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1, LIBERTYVILLE, ST, 2338 ACAR 2023-01-012023-12-31 C000199 0905 TAP, JOLIET TR.# 79, WP, 477 ACSR 2023-01-012023-12-31 C000199 0ferc:OctoberMember 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember REACTS1C224303 TDC714-TDC714-2 2023-12-31 C000199 B54-EAST OREGON, Distribution, Unattended 2023-01-012023-12-31 C000199 Other (provide details in footnote): 2023-01-012023-12-31 C000199 1324 CRAWFORD, HAYFORD, UG, 1600 MM2 XLPE 2023-01-012023-12-31 C000199 Distribution- 2023-01-012023-12-31 C000199 23-0731, 23-0722, 23-0710, 23-0675, 23-0622, 23-0610, 2023-01-012023-12-31 C000199 C66-EVANSTON, Distribution, Unattended 2023-12-31 C000199 505-OAKPARK, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember TSS192 Ridgeland TR71 Replcmnt 2023-01-012023-12-31 C000199 Docket No.  docket anticipated  Low Income Rate Study 2023-01-012023-12-31 C000199 79-SPAULDING-1, Distribution, Unattended 2023-12-31 C000199 ferc:ElectricUtilityMember IGA Enhancement Program SW 2023-12-31 C000199 459-VOLLMER ROAD-1, Distribution, Unattended 2023-01-012023-12-31 C000199 20090601-0016, 39948, ER09-1145-000 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember DER and Load Forecasting SW 2023-12-31 C000199 ferc:ElectricUtilityMember REACTS 1C224302 TSS30-TSS30-03 2023-12-31 C000199 2020 REACTS LOC1-LOC2PA 2023-01-012023-12-31 C000199 0ferc:OtherInvestmentsInSubsidiaryCompaniesMember 2023-01-012023-12-31 C000199 Other Taxes, Other Taxes, IL, 2023 2022-12-31 C000199 Adjustable Block REC Prepayments 2023-01-012023-12-31 C000199 13806 SILVER LAKE - 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R. 2023-12-31 C000199 PJM TFAJ1464561.7 2023-01-012023-12-31 C000199 12205 TAP, MARENGO, WH, 477 ACSR 2023-01-012023-12-31 C000199 Purchased Electricity - Over Recovery 2023-01-012023-12-31 C000199 17008 HARBOR, UNIVERSITY, SP, 1113,2156 ACSR 2023-01-012023-12-31 C000199 B64-FRANKLIN GROVE, Distribution, Unattended 2023-12-31 C000199 TSS104 Ford City Intel Sub 2023-01-012023-12-31 C000199 Information Technology - Indirect, Exelon BSC 2023-01-012023-12-31 C000199 Energy Transition Assistance Charge, Other Taxes, IL, 2023 2023-01-012023-12-31 C000199 15501 NELSON - 3, LEE COUNTY E.C., SP, 2-1277 ACAR 2023-01-012023-12-31 C000199 Libertyville Training Cntr Cap 2023-01-012023-12-31 C000199 4621 DESPLAINES - 2, GOLF MILL, SP, 2156 ACSR 2023-01-012023-12-31 C000199 122-BELVIDERE-2, Distribution, Unattended 2023-12-31 C000199 527-PLANO, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:LandAndRightsMember Cherry Valley-Silver Lake 2023-01-012023-12-31 C000199 A71-GRASS LAKE, Distribution, Unattended 2023-12-31 C000199 W330-GLEN ELLYN, Distribution, Unattended 2023-01-012023-12-31 C000199 15509 NELSON, ROCK FALLS, ST, 1113 ACSR 2023-01-012023-12-31 C000199 B27-STILLMAN VALLEY, Distribution, Unattended 2023-01-012023-12-31 C000199 1309 CRAWFORD, FISK TERMINAL, SP, T2-1113 ACSR 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 10% 2023-01-012023-12-31 C000199 Sugar Grove TSS 2023-01-012023-12-31 C000199 14401 WAYNE - 1, SILVER LAKE, ST, 2338 ACAR 2023-01-012023-12-31 C000199 3703Y NATOMA, GALEWOOD, UG, 250 kcmil HPFF 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember TDC785 Ontario PMU Deployment 2023-12-31 C000199 of a Multi-Year Rate Plan 2022-12-31 C000199 ADMS SW 2023-01-012023-12-31 C000199 Uncollectible Accounts Expense - Under Recovery 2023-12-31 C000199 ferc:GenerationStudiesMember PJM TFAJ1464921 2023-01-012023-12-31 C000199 460-HARVEY-2, Distribution, Unattended 2023-12-31 C000199 1607 WAUKEGAN - 1, SW TIE L-4202, ST, 300CU/1113ACSR/ 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember CCB INST CONF CCB/MDM BX2 SW 2023-01-012023-12-31 C000199 70-BRADLEY-2, Distribution, Unattended 2023-01-012023-12-31 C000199 J87-LEMONT, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember Spare TR 40MVA (2-Wind) Silv L 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember Long Term Performance Plan - 4 2023-01-012023-12-31 C000199 PJM AFS-128 Crescent Ridge-Cor408.1 2023-01-012023-12-31 C000199 3710 FRANKLIN PARK, NATOMA, UG, 2000 kcmil HPFF 2023-01-012023-12-31 C000199 454-PLAINFIELD, Distribution, Unattended 2023-12-31 C000199 Various complaint and petition matters 2023-01-012023-12-31 C000199 Apollo Phase 2 W/O WPT SWferc:ElectricUtilityMember 2023-12-31 C000199 G909-DOLTON-1, Distribution, Unattended 2023-01-012023-12-31 C000199 1131-1135 W Winona - Relo 2023-01-012023-12-31 C000199 ferc:GenerationStudiesMember AF2-199 Nelson-Elec Junc 345kV561.7 2023-01-012023-12-31 C000199 149-WILMINGTON, Distribution, Unattended 2023-12-31 C000199 0708 TAP - 2, HARBOR, SP, 2156 ACSR 2023-01-012023-12-31 C000199 10803 LOCKPORT - 2, MCCOOK, SP, 2156 ACSR 2023-01-012023-12-31 C000199 13805 SILVER LAKE - 1, SW TIE L-18513, ST, 1113,2156 ACSR 2023-01-012023-12-31 C000199 Capitalized Employee Incentive Payments 2023-01-012023-12-31 C000199 ferc:UnspecifiedInvestmentsInSubsidiaryCompaniesTwoMember 0 2023-01-012023-12-31 C000199 State Income Tax, Income Tax, IL, 2023 2023-01-012023-12-31 C000199 X315-NEVA #2, Distribution, Unattended 2023-12-31 C000199 Y314-17TH STREET, Distribution, Unattended 2023-01-012023-12-31 C000199 460-HARVEY-1, Distribution, Unattended 2023-01-012023-12-31 C000199 18706 SCHAUFF ROAD - 2, KEEMIN (AMEREN), ST, 477 ACSR 2023-01-012023-12-31 C000199 Docket Nos. -    2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember TSS64 Bellwood 12kV Switchgear 2023-12-31 C000199 Commonwealth Edison 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 4% 2023-12-31 C000199 13701 JEFFERSON, GRENSHAW, UG, 2500 kcmil HPFF 2023-01-012023-12-31 C000199 12006 LOMBARD, DESPLAINES, ST, 2156 ACSR 2023-01-012023-12-31 C000199 ScheduleExtraordinaryPropertyLossesAbstract 2023-01-012023-12-31 C000199 C53-EVANSTON-2, Distribution, Unattended 2023-12-31 C000199 115-BEDFORD PARK-1, Transmission, Unattended 2023-01-012023-12-31 C000199 5104 MCCOOK - 3, BEDFORD PARK, WP, 900 ACSR 2023-01-012023-12-31 C000199 549-BERKELEY, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:UnspecifiedInvestmentsInSubsidiaryCompaniesFourMember 0 2023-12-31 C000199 15504 NELSON, N.W. STEEL & WIRE, ST, 2-1277 ACAR 2023-01-012023-12-31 C000199 5107Y MCCOOK, TERMINAL Q, UG, 1600 MM2 XLPE 2023-01-012023-12-31 C000199 Other (provide details in footnote): 2022-01-012022-12-31 C000199 0706 STATE LINE - 3, CALUMET, WP, 1113 ACSR 2023-01-012023-12-31 C000199 461-CRESTWOOD, Distribution, Unattended 2023-01-012023-12-31 C000199 23-COLLINS, Transmission, Unattended 2023-12-31 C000199 C85-NORTHBROOK-2, Distribution, Unattended 2023-12-31 C000199 SPARE TRANSFORMER-10, , 2023-12-31 C000199 ferc:ElectricUtilityMemberferc:ExciseTaxMember 2023-01-012023-12-31 C000199 ADMS - Cap Software #2 SW 2023-01-012023-12-31 C000199 127, 3.200% 2023-12-31 C000199 11702 PROSPECT HTS - 3, DES PLAINES 46, WH, 1113 ACSR 2023-01-012023-12-31 C000199 G31-RIVERDALE, Distribution, Unattended 2023-01-012023-12-31 C000199 F75-HOMEWOOD, Distribution, Unattended 2023-12-31 C000199 ferc:ElectricUtilityMember 2020 REACTS TSS60-TSS60 7 DFR 2023-01-012023-12-31 C000199 37-NATOMA, Distribution, Unattended 2023-01-012023-12-31 C000199 0704 STATE LINE - 1, RIVER E.C., ST, 336.4,477,636,111 2023-01-012023-12-31 C000199 2223 ZION - 2, ZION E.C., ST, 2338 ACAR 2023-01-012023-12-31 C000199 AC1-171 Expense 2023-01-012023-12-31 C000199 128, 2.200% 2023-12-31 C000199 1604 WAUKEGAN - 3, LIBERTYVILLE, WH, 1113 ACSR 2023-01-012023-12-31 C000199 D175-SCHILLER PARK-2, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 2020 REACTS TSS60-TDC461-2 DFR 2023-12-31 C000199 5105X RIDGELAND, TERMINAL C, UG, 1600 MM2 XLPE 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember Ucomm Fibers Svcs CED HW 2023-12-31 C000199 ferc:ElectricUtilityMember Project Post - ESS E 535 - 2 2023-01-012023-12-31 C000199 C51-DESPLAINES, Distribution, Unattended 2023-01-012023-12-31 C000199 Use Tax, Sales And Use Tax, IL, 2023 2023-12-31 C000199 E28-ALGONQUIN, Distribution, Unattended 2023-12-31 C000199 166-LEITHTON-2, Distribution, Unattended 2023-12-31 C000199 C73-TECHNY-2, Distribution, Unattended 2023-12-31 C000199 ferc:ElectricUtilityMember ComEd/PECO CC&B Impl SW 2023-12-31 C000199 2002 BRAIDWOOD - 1, DAVIS CREEK, ST, 2156 ACSR 2023-01-012023-12-31 C000199 7910 SPAULDING - 1, WAYNE, ST, 1113 ACSR 2023-01-012023-12-31 C000199 11617 GOODINGS GROVE - 2, LOCKPORT, SP, 2156 ACSR 2023-01-012023-12-31 C000199 J68-COAL CITY, Distribution, Unattended 2023-01-012023-12-31 C000199 Twombly Facility Study561.7 2023-01-012023-12-31 C000199 C92-GLENCOE, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 2020 REACTS LOC1-LOC2PA 2023-01-012023-12-31 C000199 452-GLENWOOD, Distribution, Unattended 2023-01-012023-12-31 C000199 117-PROSPECT HEIGHTS-2, Distribution, Unattended 2023-01-012023-12-31 C000199 21-0160, 21-0416, 21-0530, 21-0546, 21-0544, 21-0761 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember REACTS1C224303 TDC714-TDC714-4 2023-12-31 C000199 ferc:ElectricUtilityMember 1050 W. 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JOLIET, Distribution, Unattended 2023-01-012023-12-31 C000199 10302 LISLE - 2, LOMBARD, SP, 1113,2156,2-1113A 2023-01-012023-12-31 C000199 Land - Aurora to Elgin-Kaneferc:OtherPropertyMember 2023-01-012023-12-31 C000199 Unemployment Insurance (FUTA), Unemployment Tax, Fed, 2022 2022-12-31 C000199 C61-GARNETT, Distribution, Unattended 2023-12-31 C000199 3706 NATOMA, HIGGINS, UG, 2000 kcmil HPFF 2023-01-012023-12-31 C000199 Plymouth Court 2023-01-012023-12-31 C000199 1 items less than $250,000 2023-01-012023-12-31 C000199 443-HARVEY, Distribution, Unattended 2023-01-012023-12-31 C000199 132-GARDEN PLAIN-2, Distribution, Unattended 2023-12-31 C000199 Various ICC dockets 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember Other Projects - 3 2023-01-012023-12-31 C000199 2311 COLLINS - 2, DRESDEN, ST, 2156 ACSR 2023-01-012023-12-31 C000199 691-WAVELAND, Distribution, Unattended 2023-12-31 C000199 D242-BRIDGEVIEW, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember Long Term Performance Plan - 1 2023-12-31 C000199 Other Debit or Cr. Items (Describe, details in footnote): 2023-01-012023-12-31 C000199 Transmission Costs - Over Recovery 2022-12-31 C000199 2023-12-31 C000199 R23-BEATTIE, Distribution, Unattended 2023-12-31 C000199 12-DRESDEN-2, Distribution, Unattended 2023-12-31 C000199 J20-MISSISSIPPI, Distribution, Unattended 2023-01-012023-12-31 C000199 1223 DRESDEN - 2, ELECTRIC JUNCTION, ST, 2338 ACAR 2023-01-012023-12-31 C000199 H57-LEE, Distribution, Unattended 2023-01-012023-12-31 C000199 149-WILMINGTON-1, Distribution, Unattended 2023-12-31 C000199 ferc:ElectricUtilityMember TDC556 Berwyn Improvmnt L19202 2023-12-31 C000199 Federal Income Tax, Income Tax, Fed, 2023 2023-01-012023-12-31 C000199 234-LAKEHURST, Distribution, Unattended 2023-01-012023-12-31 C000199 B10-HARVARD, Distribution, Unattended 2023-12-31 C000199 E46-BURTON BRIDGE, Distribution, Unattended 2023-01-012023-12-31 C000199 7411 KEWANEE , AMEREN KEEMIN, ST, 477 ACSR 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember Other Debit or Cr. Items (Describe, details in footnote): 2023-01-012023-12-31 C000199 Coal to Solar 2023-12-31 C000199 A41-WAUKEGAN-1, Distribution, Unattended 2023-01-012023-12-31 C000199 H59-PAW PAW, Distribution, Unattended 2023-12-31 C000199 110 N Wacker - Cable & Conduit 2023-01-012023-12-31 C000199 H10-PRARIEVILLE, Distribution, Unattended 2023-01-012023-12-31 C000199 15503 NELSON - 2, CORDOVA, ST, 2-1227 ACAR 2023-01-012023-12-31 C000199 Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock 2023-01-012023-12-31 C000199 AE1-114 PJM Facilities Study921 2023-01-012023-12-31 C000199 J66-GOOSE LAKE, Distribution, Unattended 2023-01-012023-12-31 C000199 Manville-Pontiacferc:LandAndRightsMember 2023-12-31 C000199 Capital Lease Excess Depreciation 2022-12-31 C000199 Deferred rents 2023-01-012023-12-31 C000199 1322 CRAWFORD - 2, BEDFORD PARK, SP, 2-556.5,1113 ACSR 2023-01-012023-12-31 C000199 345 kV Overhead, , , 2023-01-012023-12-31 C000199 268-ARLINGTON, Distribution, Unattended 2023-01-012023-12-31 C000199 D46-NORTHLAKE, Distribution, Unattended 2023-12-31 C000199 B63-LANARK, Distribution, Unattended 2023-12-31 C000199 Transmission Services, PECO Energy Company 2023-01-012023-12-31 C000199 268-ARLINGTON, Distribution, Unattended 2023-12-31 C000199 ferc:LandAndRightsMember Wilton Center-Joliet 2023-01-012023-12-31 C000199 70-BRADLEY-1, Distribution, Unattended 2023-01-012023-12-31 C000199 B31-CHEMUNG, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:LandAndRightsMember Waukegan Station 354kv Switchyard 2023-12-31 C000199 ferc:ElectricUtilityMember REACTS Schmb E2016-W7415 DFR 2023-01-012023-12-31 C000199 Distribution Plant 2023-01-012023-12-31 C000199 W18-ORCHARD RD, Distribution, Unattended 2023-01-012023-12-31 C000199 X380-WRIGHTWOOD, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 79657 : IL-71 FROM 0.5MILE EAS 2023-01-012023-12-31 C000199 120-LOMBARD-1, Transmission, Attended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember NORTHPOINT ELWOOD 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember ADMS SW 2023-01-012023-12-31 C000199 2020 REACTS BF-TSS137-SS895 2023-01-012023-12-31 C000199 133-ROCK FALLS-2, Distribution, Unattended 2023-01-012023-12-31 C000199 451-MOKENA, Distribution, Unattended 2023-01-012023-12-31 C000199 Project Circle ESSE552 2023-01-012023-12-31 C000199 Federal Income Tax, Income Tax, Fed, 2023 2022-12-31 C000199 12004 LOMBARD, ELMHURST, ST, 2156 ACSR, 2338 ACAR, 2-664.8 ACSS/TW 2023-01-012023-12-31 C000199 J33-WASH ST (JOLIET), Distribution, Unattended 2023-12-31 C000199 12204 BELVEDERE - 1, PLEASANT VALLEY, ST, 1113 ACSR, 664.8A 2023-01-012023-12-31 C000199 14102 PLEASANT VALLEY, TOLLWAY, SP, 1113 ACSR, 2-556R 2023-01-012023-12-31 C000199 W102-FABYAN, Distribution, Unattended 2023-01-012023-12-31 C000199 E72-FOX RIVER GROVE, Distribution, Unattended 2023-12-31 C000199 109-APTAKISIC, Distribution, Unattended 2023-12-31 C000199 152-BUSSE-1, Distribution, Unattended 2023-12-31 C000199 114-NORTHWEST-2, Distribution, Unattended 2023-01-012023-12-31 C000199 J60-NEW LENNOX, Distribution, Unattended 2023-12-31 C000199 ferc:ElectricUtilityMember 2021 REACTS DF-STA13-STA13-07 2023-12-31 C000199 D103-RIVERSIDE, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:LandAndRightsMember Charter Grove TSS 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 2019 REACTS STA22-STA16 BBF 2023-12-31 C000199 23-COLLINS, Transmission, Unattended 2023-01-012023-12-31 C000199 220-SOUTH SCHAUMBURG, Distribution, Unattended 2023-12-31 C000199 0902 TAP - 2, DAVIS CREEK, WH, 636 ACSR 2023-01-012023-12-31 C000199 A49-WAUKEGAN, Distribution, Unattended 2023-12-31 C000199 574-BARTLETT, Distribution, Unattended 2023-01-012023-12-31 C000199 C22-LINCOLNWOOD, Distribution, Unattended 2023-12-31 C000199 237-BUFFALO GROVE, Distribution, Unattended 2023-01-012023-12-31 C000199 D179-O'HARE FIELD, Distribution, Unattended 2023-12-31 C000199 J17-TROY TWP, Distribution, Unattended 2023-01-012023-12-31 C000199 78784 : Canal btwn Madison & T 2023-01-012023-12-31 C000199 Insurance Contributions (FICA), Payroll Tax, Fed, 2023 2023-01-012023-12-31 C000199 2021 REACTS DF-STA13-STA13-07 2023-01-012023-12-31 C000199 18706 SCHAUFF ROAD - 1, KEEMIN (AMEREN), SP, 2023-01-012023-12-31 C000199 PJM AE2-341 Facility Study921 2023-01-012023-12-31 C000199 3P211002-56TH144 12 KV CONV 2023-01-012023-12-31 C000199 D177-O'HARE FIELD, Distribution, Unattended 2023-12-31 C000199 6608 EAST FRANKFORT - 3, UNIVERSITY PARK N.  E.C., ST, 1414 ACSR 2023-01-012023-12-31 C000199 8605 DAVIS CREEK - 1, BRADLEY, SP, 2-556.5,1113 ACSR 2023-01-012023-12-31 C000199 H40-WALNUT, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:LandAndRightsMember Sugar Grove TSS 2023-12-31 C000199 ferc:ElectricUtilityMember Other Projects 2023-01-012023-12-31 C000199 TOTAL Distribution Substations, , 2023-12-31 C000199 Various FERC dockets 2023-01-012023-12-31 C000199 B12-CAPRON, Distribution, Unattended 2023-12-31 C000199 ferc:AllocationOfPayrollChargedForClearingAccountsMember Clearing Accounts 2023-01-012023-12-31 C000199 234-LAKEHURST, Distribution, Unattended 2023-12-31 C000199 ferc:ElectricUtilityMember Long Term Performance Plan - 6 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember ATO Monitoring- Chicago 2023-01-012023-12-31 C000199 A15-ZION, Distribution, Unattended 2023-12-31 C000199 444-MINOOKA, Distribution, Unattended 2023-01-012023-12-31 C000199 Purchased Receivables Program - Under Recovery 2023-01-012023-12-31 C000199 ferc:GenerationStudiesMember AF2-199 Nelson-Elec Junc 345kV921 2023-01-012023-12-31 C000199 Sawyer TSS 2023-01-012023-12-31 C000199 31-GALEWOOD-2, Distribution, Unattended 2023-12-31 C000199 100 Facility Study921 2023-01-012023-12-31 C000199 contracts 2023-12-31 C000199 ferc:GenerationStudiesMember PJM AD1-039 Kendall-Tazewell926 2023-01-012023-12-31 C000199 F122-BLOOM TWP-1, Distribution, Unattended 2023-12-31 C000199 S66-PONTIAC-2, Distribution, Unattended 2023-12-31 C000199 Long Term receivable from Constellation Energy Generation, LLC (formerly Exelon Generation Company, LLC) (SFAS 143, Regulatory Liability offset) 2023-12-31 C000199 F17-PEOTONE, Distribution, Unattended 2023-01-012023-12-31 C000199 W348-BENSENVILLE-2, Distribution, Unattended 2023-01-012023-12-31 C000199 C78-MORTON GROVE, Distribution, Unattended 2023-12-31 C000199 AE1-193 PJM Facilities Study-K561.6ferc:TransmissionStudiesMember 2023-01-012023-12-31 C000199 STA11 Fisk Cap Bank 2023-01-012023-12-31 C000199 W118-KENDALL TWP, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 2020 REACTS TSS48-TSS48 DFR 2023-12-31 C000199 PJM AE1-070 Elwood 345 kV Faci921 2023-01-012023-12-31 C000199 Microgrid Prepayment 2022-12-31 C000199 C26-MT PROSPECT, Distribution, Unattended 2023-12-31 C000199 11606 GOODINGS GROVE, BEDFORD PARK, ST, 900 ACSR 2023-01-012023-12-31 C000199 Various FERC dockets 2023-12-31 C000199 TOTAL Transmission Substations, , 2023-01-012023-12-31 C000199 H66-PLANO, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember REACTS Schmb E2016-W7415 DFR 2023-12-31 C000199 ferc:ElectricUtilityMember 168 N ABERDEEN PERM 2023-12-31 C000199 480-VETERANS, Distribution, Unattended 2023-12-31 C000199 B19-BELVIDERE-1, Distribution, Unattended 2023-12-31 C000199 214-HOFFMAN ESTATES, Distribution, Unattended 2023-12-31 C000199 ferc:ElectricUtilityMember Elgin Security Fence 2023-12-31 C000199 Carbon Mitigation Credit 2022-12-31 C000199 Transmission Costs - Under Recovery 2022-12-31 C000199 ferc:ElectricUtilityMember Long Term Performance Plan - 9 2023-01-012023-12-31 C000199 Cash Flow Swap Settlement Costs 2023-01-012023-12-31 C000199 15616 CHERRY VALLEY - 1, SILVER LAKE, ST, 2338 ACAR, 2156 ACSR 2023-01-012023-12-31 C000199 0ferc:CaptialStockMember 2022-12-31 C000199 ferc:ElectricUtilityMember L17105 Wood Pole Replac 2023-12-31 C000199 G83-HARVEY, Distribution, Unattended 2023-12-31 C000199 H10-PRARIEVILLE, Distribution, Unattended 2023-12-31 C000199 A94-DRUCE LAKE, Distribution, Unattended 2023-01-012023-12-31 C000199 Attachment H-13A of PJM of OATT - Revised, Docket No. ER14-1728-000 2023-01-012023-12-31 C000199 220-SOUTH SCHAUMBURG, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:IncomeTaxMember 2022-12-31 C000199 18407 ELK GROVE - 2, TONNE, T, 1113 ACSR 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember REACTS 1C224303TDC714-TDC714-1 2023-01-012023-12-31 C000199 B86-CLARE, Distribution, Unattended 2023-12-31 C000199 750-CRAGIN, Distribution, Unattended 2023-12-31 C000199 ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract 2023-01-012023-12-31 C000199 Vehicle License-Local, Other License And Fees Tax, IL, 2022 2023-01-012023-12-31 C000199 0622 BYRON - 2, CHERRY VALLEY, SP, 2156 ACSR 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 2021 REACTS STA13_2 FOH 2023-01-012023-12-31 C000199 15925 NORTHBROOK, SKOKIE 88, SP, 2156 ACSR 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember Chicago North EVCS 2023 2023-01-012023-12-31 C000199 5105 RIDGELAND, MCCOOK, ST, 900,1113 ACSR 2023-01-012023-12-31 C000199 Nelson Facility Study - Elec Junction921 2023-01-012023-12-31 C000199 ferc:OtherTaxMember 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember NORTH VO TSS103 LISLE 2023-12-31 C000199 88-SKOKIE-2, Distribution, Unattended 2023-01-012023-12-31 C000199 NRG Power Marketing, LLC , OS, 2023-01-012023-12-31 C000199 Accrued Vacation Pay 2023-01-012023-12-31 C000199 1808 WILL COUNTY - 1, GOODINGS GROVE, ST, 900 ACSR 2023-01-012023-12-31 C000199 11301WATERMAN - 2, SANDWICH, WP, 2-556.5,1113 ACSR 2023-01-012023-12-31 C000199 193-MCHENRY-1, Distribution, Unattended 2023-01-012023-12-31 C000199 124-MARYLAND, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 3P211002-56TH144 12 KV CONV 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 1P230200: New Feeder Y3037 2023-12-31 C000199 A91-ZION, Distribution, Unattended 2023-12-31 C000199 W349-BENSENVILLE, Distribution, Unattended 2023-12-31 C000199 207-TONNE-1, Distribution, Unattended 2023-12-31 C000199 X310-ALBANY PARK, Distribution, Unattended 2023-12-31 C000199 F36-GOODENOW, Distribution, Unattended 2023-12-31 C000199 1227 DRESDEN - 1, MULBERRY, SP, 2156 ACSR, 2-1033.5 ACSS/TW 2023-01-012023-12-31 C000199 11701 PROSPECT HTS - 1, DES PLAINES 46, SP, 1113 ACSR 2023-01-012023-12-31 C000199 D69-BROADVIEW-1, Distribution, Unattended 2023-01-012023-12-31 C000199 SPARE TRANSFORMER-5, , 2023-01-012023-12-31 C000199 77-MAZON, Distribution, Unattended 2023-01-012023-12-31 C000199 W340-WEISBROOK, Distribution, Unattended 2023-01-012023-12-31 C000199 PMU Analytics 2023-01-012023-12-31 C000199 Common Stock 2023-01-012023-12-31 C000199 10801 LOCKPORT, LOMBARD, ST, 2156 ACSR 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember RELO TSS101 Itasca 345kV - GIS 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember Other Projects - 1 2023-01-012023-12-31 C000199 1809 WILL COUNTY - 1, NORMANTOWN, ST, 1033.5ACSS/TW, 2- 2023-01-012023-12-31 C000199 1322 CRAWFORD - 1, BEDFORD PARK, ST, 1113 ACSR 2023-01-012023-12-31 C000199 J24-LISBON, Distribution, Unattended 2023-12-31 C000199 ferc:GenerationStudiesMember JM MISO J955 FACILITIES STUDY561.7 2023-01-012023-12-31 C000199 Mutual Assistance, Baltimore Gas & Electric 2023-01-012023-12-31 C000199 149-WILMINGTON-2, Distribution, Unattended 2023-01-012023-12-31 C000199 X301-BELMONT, Distribution, Unattended 2023-12-31 C000199 138 kV Overhead, , , 2023-01-012023-12-31 C000199 R22-WEST, Distribution, Unattended 2023-01-012023-12-31 C000199 409-SOUTH JOLIET, Distribution, Unattended 2023-12-31 C000199 ferc:ElectricUtilityMember 2020 REACTS TSS60-TSS60 7 DFR 2023-12-31 C000199 W38-DOWNERS GROVE TW, Distribution, Unattended 2023-01-012023-12-31 C000199 9203 MCLEAN - 1, BROKAW (AMEREN), SP, 2-1277 ACAR 2023-01-012023-12-31 C000199 12204 BELVEDERE - 2, PLEASANT VALLEY, SP, 664.8ACSS/TW 2023-01-012023-12-31 C000199 Deferred Asset Retirement Obligation Costs 2022-12-31 C000199 Renewable Portfolio Standard Costs - Rider REA 2022-12-31 C000199 ferc:GenerationStudiesMember AE1-114 PJM Facilities Study561.7 2023-01-012023-12-31 C000199 Long Term Performance Plan - 11 2023-01-012023-12-31 C000199 5107 MCCOOK - 1, RIDGELAND, ST, 1033.5ACSS/TW, 2- 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 0 2022-12-31 C000199 123-MARGENGO, Distribution, Unattended 2023-01-012023-12-31 C000199 C31-WILMETTE, Distribution, Unattended 2023-12-31 C000199 Enel Trading North America, LLC , OS, 2023-01-012023-12-31 C000199 D46-NORTHLAKE, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 2020 REACTS TSS73 to TSS179 2023-01-012023-12-31 C000199 J54-LORENZO, Distribution, Unattended 2023-01-012023-12-31 C000199 E71-DORR TWP-1, Distribution, Unattended 2023-12-31 C000199 ferc:GenerationStudiesMember Rock Falls Garden Facility Study926 2023-01-012023-12-31 C000199 W384-BUTTERFIELD-2, Distribution, Unattended 2023-01-012023-12-31 C000199 132, 3.150% 2023-01-012023-12-31 C000199 BES - Residential Space Heating 2023-01-012023-12-31 C000199 J68-COAL CITY, Distribution, Unattended 2023-12-31 C000199 561-BOLINGBROOK, Distribution, Unattended 2023-01-012023-12-31 C000199 G125-OAK LAWN, Distribution, Unattended 2023-12-31 C000199 132-GARDEN PLAIN-2, Distribution, Unattended 2023-01-012023-12-31 C000199 558-WESTMONT-1, Distribution, Unattended 2023-12-31 C000199 Chicago Use Tax, Sales And Use Tax, IL, 2023 2023-12-31 C000199 527-PLANO, Distribution, Unattended 2023-12-31 C000199 Skydio Cloud 3yr Subscription Purchase 2023-12-31 C000199 W64-TRI STATE-1, Distribution, Unattended 2023-12-31 C000199 D15-CICERO, Distribution, Unattended 2023-01-012023-12-31 C000199 Z335-SOUTH CHICAGO, Distribution, Unattended 2023-12-31 C000199 B36-POLO, Distribution, Unattended 2023-12-31 C000199 51-MCCOOK-3, Distribution, Attended 2023-12-31 C000199 Vehicle License-Local, Other License And Fees Tax, IL, 2023 2023-12-31 C000199 A57-BEACH, Distribution, Unattended 2023-01-012023-12-31 C000199 93915 MULBERRY - 2, TAZEWELL (CLICO), ST, 2-1277 ACAR, 2338 ACAR 2023-01-012023-12-31 C000199 Mole Creek Facility Study561.7 2023-01-012023-12-31 C000199 577-SOUTH ELGIN-1, Distribution, Unattended 2023-01-012023-12-31 C000199 Major Projects: 2023-01-012023-12-31 C000199 8607 DAVIS CREEK - 3, WILMINGTON, WP, 636 ACSR, 113 ACSR 2023-01-012023-12-31 C000199 20130429-5169, 41393, ER09-1145-000 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember STA11 Fisk Cap Bank 2023-01-012023-12-31 C000199 93913 MULBERRY - 1, MOLE CREEK, SP, 2-1277 ACAR, 2156 ACSR 2023-01-012023-12-31 C000199 F122-BLOOM TWP-2, Distribution, Unattended 2023-01-012023-12-31 C000199 W46-NAPERVILLE, Distribution, Unattended 2023-01-012023-12-31 C000199 77-MAZON, Distribution, Unattended 2023-12-31 C000199 0102 LASALLE - 1, PLANO, ST, 2-1277 ACAR 2023-01-012023-12-31 C000199 C3-HIGHLAND PARK-1, Distribution, Unattended 2023-01-012023-12-31 C000199 15515 NELSON, SCHAUFF ROAD, SP, 2-556.5, 1590 ACSR 2023-01-012023-12-31 C000199 59-CICERO-2, Distribution, Unattended 2023-01-012023-12-31 C000199 79-SPAULDING, Distribution, Unattended 2023-01-012023-12-31 C000199 16-WAUKEGAN-1, Transmission, Unattended 2023-01-012023-12-31 C000199 A91-ZION, Distribution, Unattended 2023-01-012023-12-31 C000199 D69-BROADVIEW-2, Distribution, Unattended 2023-12-31 C000199 ferc:ElectricUtilityMember 210 N Aberdeen - 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3, BELLWOOD, WP, 900,1113 ACSR 2023-01-012023-12-31 C000199 215-HOWARD, Distribution, Unattended 2023-12-31 C000199 431-SHOREWOOD, Distribution, Unattended 2023-01-012023-12-31 C000199 ICC Financing Authority Fees 2023-01-012023-12-31 C000199 ferc:OtherPropertyMember Distribution Plant (Land and/or Rights): 2023-01-012023-12-31 C000199 15625 CHERRY VALLEY - 1, WEMPLETOWN, ST, 1113,2156 ACSR 2023-01-012023-12-31 C000199 17712 BURNHAM - 1, CHICAGO HTS, SP, 1113 ACSR 2023-01-012023-12-31 C000199 0624 BYRON - 1, WEMPLETOWN, ST, 2156 ACSR 2023-01-012023-12-31 C000199 11413 NORTHWEST, DIVERSEY, UG, 2000 kcmil HPFF,2 2023-01-012023-12-31 C000199 88-SKOKIE-2, Distribution, Unattended 2023-12-31 C000199 W13-ELDAMAIN, Distribution, Unattended 2023-01-012023-12-31 C000199 8810 SKOKIE 88 - 2, DEVON, WP, 1113 ACSR 2023-01-012023-12-31 C000199 83-GLIDDEN-1, Distribution, Unattended 2023-01-012023-12-31 C000199 414-ROBERTS ROAD, Distribution, Unattended 2023-01-012023-12-31 C000199 D80-BROADVIEW, Distribution, Unattended 2023-12-31 C000199 7611 BLUE ISLAND - 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3, ELWOOD E.C., ST, 2338 ACAR 2023-01-012023-12-31 C000199 D133-RIVER GROVE-1, Distribution, Unattended 2023-01-012023-12-31 C000199 W115-GLENWOOD PARK, Distribution, Unattended 2023-01-012023-12-31 C000199 Waukegan Station 354kv Switchyard 2023-01-012023-12-31 C000199 G66-OAK LAWN, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 1050 W. Van Buren - Perm 2023-01-012023-12-31 C000199 PJM AE1-070 Elwood 345 kV Faci561.6 2023-01-012023-12-31 C000199 Long Term Performance Plan - 3 2023-01-012023-12-31 C000199 C21-OPTIMA, Distribution, Unattended 2023-01-012023-12-31 C000199 ISO J1377 - PJM Facilities926 2023-01-012023-12-31 C000199 E24-CARY, Distribution, Unattended 2023-12-31 C000199 10321 LISLE , LOMBARD, ST, 2156 ACSR 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 5P2302: new feeder D3429 2023-01-012023-12-31 C000199 260-DUNDEE, Distribution, Unattended 2023-12-31 C000199 372-STERLING, Distribution, Unattended 2023-12-31 C000199 W43-DOWNERS GROVE, Distribution, Unattended 2023-01-012023-12-31 C000199 156-CHERRY VALLEY, Transmission, Unattended 2023-12-31 C000199 ferc:ElectricUtilityMember 6001 S Stony Island Ave - OPC 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 2021 F.A.U.L.T. Switch Install 2023-12-31 C000199 15503 NELSON - 3, CORDOVA, SP, 2-1277 ACAR 2023-01-012023-12-31 C000199 2222 ZION - 3, ATC, ST, 2156 ACSR 2023-01-012023-12-31 C000199 100 Facility Study561.7 2023-01-012023-12-31 C000199 87495: NBSW-905,925,999 Belle 2023-01-012023-12-31 C000199 B89-AFTON, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:GenerationStudiesMember 100 Facility Study561.7 2023-01-012023-12-31 C000199 ferc:Quarter1Member 0 2023-01-012023-12-31 C000199 D149-ELMWOOD PARK, Distribution, Unattended 2023-12-31 C000199 S19-TONICA, Distribution, Unattended 2023-01-012023-12-31 C000199 Legal Governance - Direct, Exelon BSC 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember RELO TSS101 Itasca 345kV-Line 2023-01-012023-12-31 C000199 42-ROUND LAKE-2, Distribution, Unattended 2023-01-012023-12-31 C000199 15301 TAYLOR, GRENSHAW, UG, 1600 MM2 XLPE 2023-01-012023-12-31 C000199 194-SABROOKE-2, Distribution, Attended 2023-12-31 C000199 0906 JOLIET - 1, WILL COUNTY, ST, 477, 900, 1113, T2-556.5 ACSR, 664.8 ACSS/TW 2023-01-012023-12-31 C000199 A27-WADSWORTH-2, Distribution, Unattended 2023-01-012023-12-31 C000199 Mole Creek Facility Study926 2023-01-012023-12-31 C000199 Power Operated Equipment 2023-01-012023-12-31 C000199 569-SUGAR GROVE-1, Distribution, Unattended 2023-12-31 C000199 0302 POWERTON - 2, MOLE CREEK, ST, 2-1277 ACAR 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember EU GIS CORE SW 2023-01-012023-12-31 C000199 B25-MONROE CENTER, Distribution, Unattended 2023-01-012023-12-31 C000199 11105 ELECTRIC JUNCTION - 1, AURORA E.C., ST, 1113 ACSR 2023-01-012023-12-31 C000199 J21-AUX SABLE TWP, Distribution, Unattended 2023-01-012023-12-31 C000199 126, 4.000% 2023-01-012023-12-31 C000199 94507 CRETE E.C. - 1, N.I.P.S.CO., ST, 1414 ACSR, 2156 A 2023-01-012023-12-31 C000199 375-WEST DEKALB, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:LandAndRightsMember Sugar Grove TSS 2023-01-012023-12-31 C000199 W119-BRISTOL TWP, Distribution, Unattended 2023-01-012023-12-31 C000199 453-WOODHILL, Distribution, Unattended 2023-01-012023-12-31 C000199 15621 CHERRY VALLEY - 2, DIXON, SP, 1113 ACSR 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 12 kV DA Program X4069 2023-12-31 C000199 AF2-349 Garden Prairie 345 kV921 2023-01-012023-12-31 C000199 W28-SUNSET PARK, Distribution, Unattended 2023-12-31 C000199 ferc:ElectricUtilityMember TSS112 Ridgeland - TR71 Matrl 2023-12-31 C000199 CULLINAN NEW FEEDER 2023-01-012023-12-31 C000199 G64-BLUE ISLAND, Distribution, Unattended 2023-01-012023-12-31 C000199 SPARE TRANSFORMER-4, , 2023-12-31 C000199 ferc:SchedulingSystemControlAndDispatchMember 2023-01-012023-12-31 C000199 1108 FISK, QUARRY, SP, 1113ACSR 2023-01-012023-12-31 C000199 PJM AD2-047 Davis Creek 138kV561.6 2023-01-012023-12-31 C000199 207-TONNE-1, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember BCM Controlled Generation 2023-01-012023-12-31 C000199 B-2, National Electric Energy Testing, Research and , 2023-01-012023-12-31 C000199 X380-WRIGHTWOOD, Distribution, Unattended 2023-12-31 C000199 0, 0 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 12 kV DA Program X4069 2023-01-012023-12-31 C000199 W202-ELGIN, Distribution, Unattended 2023-12-31 C000199 Long Term Performance Plan - 6 2023-01-012023-12-31 C000199 2021 F.A.U.L.T. Switch Install 2023-01-012023-12-31 C000199 11106 ELECTRIC JUNCTION - 2, WATERMAN, SP, 2-556.5 ACSR 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember SBA EDGE LINE EXTENSION 2023-12-31 C000199 0ferc:UnspecifiedInvestmentsInSubsidiaryCompaniesSixMember 2023-01-012023-12-31 C000199 ferc:LandAndRightsMember Plato Center - 1 2023-12-31 C000199 D62-HILLSIDE, Distribution, Unattended 2023-12-31 C000199 11902 LANCASTER - 2, MARYLAND, ST, 1113 ACSR 2023-01-012023-12-31 C000199 8221 CROSBY - 2, ROCKWELL, SP, 1113 ACSR 2023-01-012023-12-31 C000199 15511 NELSON - 2, DIXON R/W, SP, 1113 ACSR 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember TSS82 CROSBY SEC TECHNOLOGY 2023-01-012023-12-31 C000199 86-DAVIS CREEK-2, Distribution, Unattended 2023-12-31 C000199 8P240200 RLV F5373 2023-01-012023-12-31 C000199 D194-STONE PARK, Distribution, Unattended 2023-12-31 C000199 14403 WAYNE - 1, AURORA E.C., ST, 1113 ACSR 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember Other Accounts (Specify, details in footnote): 2023-01-012023-12-31 C000199 1309 FISK TERMINAL, WEST LOOP, UG, 1600mm2 XLPE 2023-01-012023-12-31 C000199 230-ANTIOCH, Distribution, Unattended 2023-01-012023-12-31 C000199 12411 MARYLAND - 1, DIXON, ST, 3/0 CO 2023-01-012023-12-31 C000199 194-SABROOKE-1, Distribution, Attended 2023-12-31 C000199 TOTAL Distribution Substations, , 2023-01-012023-12-31 C000199 15502 NELSON - 1, ELECTRIC JUNCTION, ST, 2-1033.5 ACSS/TW 2023-01-012023-12-31 C000199 Purchased Electricity - FERC 494 Refund 2022-12-31 C000199 X315-NEVA #1, Distribution, Unattended 2023-01-012023-12-31 C000199 ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract 2023-01-012023-12-31 C000199 Franchise, Franchise Tax, IL, 2022 2023-12-31 C000199 Vacation pay and payroll taxes pending proper accounting 2023-01-012023-12-31 C000199 125, 3.700% 2023-12-31 C000199 148-WEST LOOP, Transmission, Unattended 2023-12-31 C000199 499-WEBER, Distribution, Unattended 2023-01-012023-12-31 C000199 C81-LINCOLNWOOD, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember CCB INST CONF CCB/MDM BX2 SW 2023-12-31 C000199 Long Term Performance Plan - 8 2023-01-012023-12-31 C000199 114, 4.600% 2023-12-31 C000199 TSS64 Bellwood 12kV Switchgear 2023-01-012023-12-31 C000199 ferc:LandAndRightsMember Chicago-Northwestern R. R. 2023-01-012023-12-31 C000199 88-SKOKIE, Distribution, Unattended 2023-01-012023-12-31 C000199 39-PORTAGE, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember NTT Data Center Phase 2 2023-01-012023-12-31 C000199 185-TOLLWAY, Transmission, Unattended 2023-01-012023-12-31 C000199 10721 DIXON - 3, STILLMAN VALLEY, WP, 1113 ACSR 2023-01-012023-12-31 C000199 12411 TAP, STERLING, SP, 1113 ACS 2023-01-012023-12-31 C000199 1605 WAUKEGAN - 3, HIGHLAND PARK, SP, 1113,2156 ACSR 2023-01-012023-12-31 C000199 D 229-LYONS TWP-2, Distribution, Unattended 2023-12-31 C000199 113-WATERMAN, Distribution, Unattended 2023-12-31 C000199 ferc:GenerationStudiesMember PJM TFAJ1464561.7 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember NTT Data Center Phase 2 2023-12-31 C000199 Electricity Distribution Tax, Other Taxes, IL, 2023 2022-12-31 C000199 0404 QUAD CITIES, N.W. STEEL & WIRE, ST, 2-1277 ACAR 2023-01-012023-12-31 C000199 SPARE TRANSFORMER-5, , 2023-12-31 C000199 122, 2.950% 2023-01-012023-12-31 C000199 ferc:GenerationStudiesMember Shady Oaks Facility Study408.1 2023-01-012023-12-31 C000199 1221 DRESDEN - 1, WOLFS, ST, 2338 ACAR 2023-01-012023-12-31 C000199 1324 CRAWFORD - 1, BEDFORD PARK, ST, 1113 ACSR 2023-01-012023-12-31 C000199 851-WASHTENAW, Distribution, Unattended 2023-01-012023-12-31 C000199 Sales Tax, Sales And Use Tax, IL, 2023 2022-12-31 C000199 64-BELLWOOD-1, Distribution, Unattended 2023-12-31 C000199 372-STERLING, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 78624 : Franklin Ave OH Reloca 2023-12-31 C000199 550-CLEARING, Distribution, Unattended 2023-12-31 C000199 D15-CICERO, Distribution, Unattended 2023-12-31 C000199 Rock Falls Garden Facility Study408.1 2023-01-012023-12-31 C000199 2021 REACTS DF-STA13-STA13-03ferc:ElectricUtilityMember 2023-12-31 C000199 745-I.C.AIR RIGHTS, Distribution, Unattended 2023-01-012023-12-31 C000199 121-FREEPORT-2, Distribution, Unattended 2023-12-31 C000199 S41-EPPARDS POINT, Distribution, Unattended 2023-12-31 C000199 ferc:ElectricUtilityMember IP2 PCKT RELIABILITY-FDR H261 2023-12-31 C000199 505-OAKPARK, Distribution, Unattended 2023-12-31 C000199 13806 SILVER LAKE - 3, SW TIE L-18513, WP, 477,1113 ACSR 2023-01-012023-12-31 C000199 H55-WATERMAN, Distribution, Unattended 2023-12-31 C000199 Insurance recoveries related to third party claims 2023-12-31 C000199 12-DRESDEN-1, Transmission, Unattended 2023-12-31 C000199 19-0875, 19-0940, 19-1064, 20-0627, 20-0703, 20-0629 2023-01-012023-12-31 C000199 See footnote for details 2023-01-012023-12-31 C000199 10804 LOCKPORT - 2, MCCOOK, SP, 2156 ACSR 2023-01-012023-12-31 C000199 18502 TOLLWAY - 4, LIBERTYVILLE, SP, 2156 ACSR 2023-01-012023-12-31 C000199 J40 - WESTERN AVE, Distribution, Unattended 2023-12-31 C000199 11704 PROSPECT HEIGHTS - 1, APTAKISIC, ST, 1113 ACSR 2023-01-012023-12-31 C000199 0716 ILL-IND STATE LINE - 2, CALUMET, SP, 2-1277.2 ACAR / 1 2023-01-012023-12-31 C000199 A31-FOX LAKE, Distribution, Unattended 2023-01-012023-12-31 C000199 C83-EVANSTON, Distribution, Unattended 2023-01-012023-12-31 C000199 AMI Meter Accelerated Depreciation 2022-12-31 C000199 Transfer to appropriated retained earnings for payment of future dividends 2022-01-012022-12-31 C000199 W26-BIG TIMBER, Distribution, Unattended 2023-12-31 C000199 D173-ELMWOOD PARK, Distribution, Unattended 2023-01-012023-12-31 C000199 11106 TAP, CREGO ROAD, SP, 2-556.5 ACSR,1113 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember Other Debit or Cr. Items (Describe, details in footnote):ferc:ElectricPlantInServiceMember 2023-01-012023-12-31 C000199 E17-WONDER LAKE, Distribution, Unattended 2023-01-012023-12-31 C000199 B26-DAVIS JUNCTION, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMemberferc:PayrollTaxMember 2023-01-012023-12-31 C000199 agreements 2023-01-012023-12-31 C000199 93505 KENDALL CO. - 2, DRESDEN, ST, 2338 ACAR, 2-1277 2023-01-012023-12-31 C000199 W236-ROSELLE, Distribution, Unattended 2023-12-31 C000199 Insurance Contributions (FICA), Payroll Tax, Fed, 2023 2022-12-31 C000199 15508 NELSON - 2, DIXON 107, SP, 477,1113 ACSR 2023-01-012023-12-31 C000199 F111-PARK FOREST, Distribution, Unattended 2023-12-31 C000199 14828 WEST LOOP, CROSBY, UG, 1600 MM2 XLPE 2023-01-012023-12-31 C000199 E79-SOUTH WONDERLAKE, Distribution, Unattended 2023-12-31 C000199 17715 BURNHAM - 2, TOWER AUTOMOTIVE, SP, 1113 ACSR 2023-01-012023-12-31 C000199 0ferc:UnspecifiedInvestmentsInSubsidiaryCompaniesThreeMember 2023-12-31 C000199 D255-FORESTVIEW, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember Retire 4kV Fdrs W405 W406 W438 2023-01-012023-12-31 C000199 W64-TRI STATE-2, Distribution, Unattended 2023-01-012023-12-31 C000199 435-COUNTRY CLUB HILLS, Distribution, Unattended 2023-12-31 C000199 15912 NORTHBROOK 159 - 2, HIGHLAND PARK, SP, 1113 ACSR,2156 ACSR 2023-01-012023-12-31 C000199 D16-LAGRANGE HIGHLANDS-2, Distribution, Unattended 2023-01-012023-12-31 C000199 Ucomm Fibers Svcs CED HW 2023-01-012023-12-31 C000199 OUTSIDE CHICAGO (UNDER 10MVA), , 2023-01-012023-12-31 C000199 Funds for Utility Job 2023-01-012023-12-31 C000199 0ferc:UnspecifiedInvestmentsInSubsidiaryCompaniesEightMember 2023-12-31 C000199 PJM AF1-030 Facility Study926 2023-01-012023-12-31 C000199 Powerton-Nevada FS AE1-163926 2023-01-012023-12-31 C000199 Long Term Restricted Cash 2022-12-31 C000199 ferc:ElectricUtilityMember TSS 135 Elmhurst Tran Hardn 2023-12-31 C000199 172-GOLF MILL-2, Distribution, Unattended 2023-01-012023-12-31 C000199 104-FORD CITY, Distribution, Unattended 2023-12-31 C000199 Chicago South Switchgear Repla 2023-01-012023-12-31 C000199 E82-RICHMOND, Distribution, Unattended 2023-01-012023-12-31 C000199 Operation Services - Direct, Exelon BSC 2023-01-012023-12-31 C000199 572-GILBERTS, Distribution, Unattended 2023-12-31 C000199 8P233700 4:12kV G53 & G56 2023-01-012023-12-31 C000199 687-NORWOOD PARK, Distribution, Unattended 2023-12-31 C000199 282 ZION, Distribution, Unattended 2023-12-31 C000199 A47-LAKE VILLA, Distribution, Unattended 2023-01-012023-12-31 C000199 0704 STATE LINE - 3, RIVER E.C., WP, 1113 ACSR 2023-01-012023-12-31 C000199 Information technology upgrades expenses 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 7% 2023-01-012023-12-31 C000199 117-PROSPECT HEIGHTS-2, Distribution, Unattended 2023-12-31 C000199 ScheduleHydroelectricGeneratingPlantStatisticsAbstract 2023-01-012023-12-31 C000199 17715 BURNHAM - 1, TOWER AUTOMOTIVE, ST, 1113 ACSR 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember L19202 HPFF Replacement 2023-01-012023-12-31 C000199 Training Program (FEJA) 2023-12-31 C000199 ferc:ElectricUtilityMember Energy Transition Assistance Charge, Other Taxes, IL, 2023 2023-01-012023-12-31 C000199 1811 WILL COUNTY - 2, GOODINGS GROVE, SP, 900 ACSR 2023-01-012023-12-31 C000199 539-WARRENVILLE, Distribution, Unattended 2023-12-31 C000199 C55-PARK RIDGE, Distribution, Unattended 2023-01-012023-12-31 C000199 C28-SKOKIE, Distribution, Unattended 2023-01-012023-12-31 C000199 101-ITASCA-2, Distribution, Unattended 2023-12-31 C000199 240-CARY, Distribution, Unattended 2023-12-31 C000199 Materials, Pepco Holdings LLC 2023-01-012023-12-31 C000199 R14-NORTH, Distribution, Unattended 2023-12-31 C000199 Public Utility Fund, Other Taxes, IL, 2023 2023-01-012023-12-31 C000199 B-2, Watson & Renner,566 2023-01-012023-12-31 C000199 Z307-NEWCASTLE, Distribution, Unattended 2023-01-012023-12-31 C000199 D133-RIVER GROVE-2, Distribution, Unattended 2023-01-012023-12-31 C000199 152-BUSSE-1, Distribution, Unattended 2023-01-012023-12-31 C000199 D51-NORTHLAKE, Distribution, Unattended 2023-12-31 C000199 5118 MCCOOK - 1, BELLWOOD, SP, 1113 AA / 1113 AC 2023-01-012023-12-31 C000199 S36-VERONA, Distribution, Unattended 2023-12-31 C000199 0907 JOLIET - 1, WOLFS, ST, 300 CU / 1113 ACW 2023-01-012023-12-31 C000199 11103 ELECTRIC JUNCTION - 2, AURORA E.C., ST, 1113 ACSR 2023-01-012023-12-31 C000199 TSS114 Northwest PMU Deploymnt 2023-01-012023-12-31 C000199 ferc:GenerationStudiesMember AF-2041 Nelson-Elec Junc 345kV921 2023-01-012023-12-31 C000199 J58-MANHATTAN, Distribution, Unattended 2023-01-012023-12-31 C000199 Operations Services - Indirect, Exelon BSC 2023-01-012023-12-31 C000199 D69-BROADVIEW-2, Distribution, Unattended 2023-01-012023-12-31 C000199 3P190201-Z11884 2023-01-012023-12-31 C000199 Manville-Pontiacferc:LandAndRightsMember 2023-01-012023-12-31 C000199 Capital Lease Excess Depreciation 2023-12-31 C000199 S39-MINONK, Distribution, Unattended 2023-12-31 C000199 H91-PROPHETSTOWN, Distribution, Unattended 2023-01-012023-12-31 C000199 ESSG314 Christ Hospital 2023-01-012023-12-31 C000199 B53-OREGON, Distribution, Unattended 2023-01-012023-12-31 C000199 113, 3.800% 2023-01-012023-12-31 C000199 12001 LOMBARD, ITASCA, ST, 2156 ACSR 2023-01-012023-12-31 C000199 K32-AROMA PARK, Distribution, Unattended 2023-12-31 C000199 E19-ISLAND LAKE, Distribution, Unattended 2023-01-012023-12-31 C000199 Estimated Illinois Distribution Tax Refund 2022-12-31 C000199 D11-CENTERPOINT, Distribution, Unattended 2023-01-012023-12-31 C000199 Information Technology - Direct, Exelon BSC 2023-01-012023-12-31 C000199 RITELine Illinois, LLC 2023-01-012023-12-31 C000199 222-LAKE BLUFF, Distribution, Unattended 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember oneMDS Mobile Dispatch - SW 2023-01-012023-12-31 C000199 W38-DOWNERS GROVE TW, Distribution, Unattended 2023-12-31 C000199 A47-LAKE VILLA, Distribution, Unattended 2023-12-31 C000199 H50-EARLVILLE, Distribution, Unattended 2023-01-012023-12-31 C000199 0707 TAP, TAP TO T-3030, ST, 2156 ACSR 2023-01-012023-12-31 C000199 C81-LINCOLNWOOD, Distribution, Unattended 2023-12-31 C000199 1317 CRAWFORD, FISK, UG, 2500 HPFF 2023-01-012023-12-31 C000199 AE1-194 PJM Facilities Study-K408.1ferc:TransmissionStudiesMember 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember Maywood Lab expansion 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember L7542 Customer Count 2023-12-31 C000199 AE1-205 PJM Facilities Study926 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember Project Post - L21408 2023-12-31 C000199 ferc:GenerationStudiesMember PJM AE2-173: MCLEAN 345 KV561.7 2023-01-012023-12-31 C000199 14402 WAYNE - 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2, N.I.P.S.CO., SP, 1414 ACSR, 2156 A 2023-01-012023-12-31 C000199 See footnote for details 2023-01-012023-12-31 C000199 TOTAL CHICAGO (UNDER 10MVA), , 2023-12-31 C000199 Rochelle Franchise Fees to be amortized through 2070 2023-12-31 C000199 48-HIGHLAND PARK-1, Distribution, Unattended 2023-01-012023-12-31 C000199 A64-LIBERTYVILLE, Distribution, Unattended 2023-01-012023-12-31 C000199 B12-CAPRON, Distribution, Unattended 2023-01-012023-12-31 C000199 2019 REACTS TSS157-DCK15 BBF 2023-01-012023-12-31 C000199 126-STATE, Distribution, Unattended 2023-01-012023-12-31 C000199 555-GLEN ELLYN, Distribution, Unattended 2023-01-012023-12-31 C000199 G 19 TINLEY PARK, Distribution, Unattended 2023-12-31 C000199 111-ELECTRIC JUNCTION-3, Distribution, Unattended 2023-12-31 C000199 Vehicle License-Local, Other License And Fees Tax, IL, 2023 2023-01-012023-12-31 C000199 Microgrid Prepayment 2023-12-31 C000199 581-FRONTENAC, Distribution, Unattended 2023-01-012023-12-31 C000199 B44-WARREN, Distribution, Unattended 2023-01-012023-12-31 C000199 B19-BELVIDERE-2, Distribution, Unattended 2023-01-012023-12-31 C000199 80-PONTIAC MIDPOINT-1, Transmission, Unattended 2023-12-31 C000199 Initial payments - 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ICC fees and other issuance costs to be 2023-01-012023-12-31 C000199 17723 BURNHAM - 2, STATE LINE, ST, 2156 ACSR 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember GIS Transmission SW 2023-01-012023-12-31 C000199 Estimated Illinois Distribution Tax Refund 2023-01-012023-12-31 C000199 11613 GOODINGS GROVE - 1, WILTON CENTER, SP, 2156 ACSR, 2338 ACAR 2023-01-012023-12-31 C000199 ferc:GenerationStudiesMember ISO J1377 - PJM Facilities408.1 2023-01-012023-12-31 C000199 17705 BURNHAM, SHEFFIELD (NIPSCO), ST, 2338 ACAR 2023-01-012023-12-31 C000199 7612 BLUE ISLAND - 2, WILDWOOD, SP, 900 ACSR 2023-01-012023-12-31 C000199 NORTHPOINT ELWOOD 2023-01-012023-12-31 C000199 Renewable Energy Swaps 2023-12-31 C000199 42-ROUND LAKE-2, Distribution, Unattended 2023-12-31 C000199 17907 DAVIS CREEK - 1, BLOOM, SP, 2156 ACSR 2023-01-012023-12-31 C000199 D45-LEYDEN TWP, Distribution, Unattended 2023-01-012023-12-31 C000199 D44-COUNTRYSIDE, Distribution, Unattended 2023-01-012023-12-31 C000199 0908 JOLIET - 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PJM Facilities921 2023-01-012023-12-31 C000199 E69-ROLLING MEADOWS, Distribution, Unattended 2023-01-012023-12-31 C000199 oneMDS Mobile Dispatch - SW 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 2020 REACTS TSS193-TSS193 DFR 2023-12-31 C000199 Project Circle NEW ESSferc:ElectricUtilityMember 2023-12-31 C000199 B86-CLARE, Distribution, Unattended 2023-01-012023-12-31 C000199 Heavy-duty Trucks 2023-01-012023-12-31 C000199 ferc:UnspecifiedInvestmentsInSubsidiaryCompaniesFourMember 0 2022-12-31 C000199 ferc:ElectricUtilityMember ADMS Task Force - HW 2023-12-31 C000199 J16-EASTERN AVE (JOLIET)-1, Distribution, Unattended 2023-01-012023-12-31 C000199 AE1-205 PJM Facilities Study561.7 2023-01-012023-12-31 C000199 ferc:ElectricUtilityMember 1P190001-Install 5th TR 2023-01-012023-12-31 C000199 Stores Expense Undistributed 2023-01-012023-12-31 C000199 577-SOUTH ELGIN-2, Distribution, Unattended 2023-01-012023-12-31 C000199 133, 3.850% 2023-12-31 C000199 Plato Center - 1 2023-01-012023-12-31 C000199 80-PONTIAC MIDPOINT-2, Distribution, Unattended 2023-01-012023-12-31 C000199 Shady Oaks Facility Study408.1 2023-01-012023-12-31 C000199 34kV Resiliency-L19342 Part 1 2023-01-012023-12-31 C000199 2224 ZION - 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THIS FILING IS
Item 1:
An Initial (Original) Submission
OR
Resubmission No.

FERC FINANCIAL REPORT
FERC FORM No. 1: Annual Report of
Major Electric Utilities, Licensees
and Others and Supplemental
Form 3-Q: Quarterly Financial Report

These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature
Exact Legal Name of Respondent (Company)

Commonwealth Edison Company
Year/Period of Report

End of:
2023
/
Q4


INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

  1. Purpose

    FERC Form No. 1 (FERC Form 1) is an annual regulatory requirement for Major electric utilities, licensees and others (18 C.F.R. § 141.1). FERC Form No. 3-Q ( FERC Form 3-Q) is a quarterly regulatory requirement which supplements the annual financial reporting requirement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities, licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be non-confidential public use forms.
  2. Who Must Submit

    Each Major electric utility, licensee, or other, as classified in the Commission’s Uniform System of Accounts Prescribed for Public Utilities, Licensees, and Others Subject To the Provisions of The Federal Power Act (18 C.F.R. Part 101), must submit FERC Form 1 (18 C.F.R. § 141.1), and FERC Form 3-Q (18 C.F.R. § 141.400).

    Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following:
    1. one million megawatt hours of total annual sales,
    2. 100 megawatt hours of annual sales for resale,
    3. 500 megawatt hours of annual power exchanges delivered, or
    4. 500 megawatt hours of annual wheeling for others (deliveries plus losses).
  3. What and Where to Submit

    1. Submit FERC Form Nos. 1 and 3-Q electronically through the eCollection portal at https://eCollection.ferc.gov, and according to the specifications in the Form 1 and 3-Q taxonomies.
    2. The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings.
    3. Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report to the Secretary of the Commission at:
      Secretary
      Federal Energy Regulatory Commission 888 First Street, NE
      Washington, DC 20426
    4. For the CPA Certification Statement, submit within 30 days after filing the FERC Form 1, a letter or report (not applicable to filers classified as Class C or Class D prior to January 1, 1984). The CPA Certification Statement can be either eFiled or mailed to the Secretary of the Commission at the address above.

      The CPA Certification Statement should:
      1. Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with the Commission's applicable Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and
      2. Be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 41.10-41.12 for specific qualifications.)

        Schedules
        Pages
        Comparative Balance Sheet 110-113
        Statement of Income 114-117
        Statement of Retained Earnings 118-119
        Statement of Cash Flows 120-121
        Notes to Financial Statements 122-123
    5. The following format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained in the letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported.

      “In connection with our regular examination of the financial statements of [COMPANY NAME] for the year ended on which we have reported separately under date of [DATE], we have also reviewed schedules [NAME OF SCHEDULES] of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.

      Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.” The letter or report must state which, if any, of the pages above do not conform to the Commission’s requirements. Describe the discrepancies that exist.
    6. Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. Further instructions are found on the Commission’s website at https://www.ferc.gov/ferc-online/ferc-online/frequently-asked-questions-faqs-efilingferc-online.
    7. Federal, State, and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q free of charge from https://www.ferc.gov/general-information-0/electric-industry-forms.
  4. When to Submit

    FERC Forms 1 and 3-Q must be filed by the following schedule:

    1. FERC Form 1 for each year ending December 31 must be filed by April 18th of the following year (18 CFR § 141.1), and
    2. FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. § 141.400).
  5. Where to Send Comments on Public Reporting Burden.

    The public reporting burden for the FERC Form 1 collection of information is estimated to average 1,168 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the FERC Form 3-Q collection of information is estimated to average 168 hours per response.

    Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S.C. § 3512 (a)).

GENERAL INSTRUCTIONS

  1. Prepare this report in conformity with the Uniform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and phrases in accordance with the USofA.
  2. Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts.
  3. Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact.
  4. For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3.
  5. Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below).
  6. Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
  7. For any resubmissions, please explain the reason for the resubmission in a footnote to the data field.
  8. Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
  9. Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used.
  10. Schedule specific instructions are found in the applicable taxonomy and on the applicable blank rendered form.
Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:

FNS - Firm Network Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. "Self" means the respondent.

FNO - Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff.

LFP - for Long-Term Firm Point-to-Point Transmission Reservations. "Long-Term" means one year or longer and” firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Reservations" are described in Order No. 888 and the Open Access Transmission Tariff. For all transactions identified as LFP, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally cancel the contract.

OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and “firm” means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.

SFP - Short-Term Firm Point-to-Point Transmission Reservations. Use this classification for all firm point-to-point transmission reservations, where the duration of each period of reservation is less than one-year.

NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions.

OS - Other Transmission Service. Use this classification only for those services which can not be placed in the above-mentioned classifications, such as all other service regardless of the length of the contract and service FERC Form. Describe the type of service in a footnote for each entry.

AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment.

DEFINITIONS
  1. Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization.
  2. Respondent -- The person, corporation, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is made.

EXCERPTS FROM THE LAW

Federal Power Act, 16 U.S.C. § 791a-825r

Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:

  1. ’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined;
  2. 'Person' means an individual or a corporation;
  3. 'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof;
  1. 'municipality means a city, county, irrigation district, drainage district, or other political subdivision or agency of a State competent under the Laws thereof to carry and the business of developing, transmitting, unitizing, or distributing power; ......
  1. "project' means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the primary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit;

"Sec. 4. The Commission is hereby authorized and empowered
  1. 'To make investigations and to collect and record data concerning the utilization of the water 'resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development costs, and relation to markets of power sites; ... to the extent the Commission may deem necessary or useful for the purposes of this Act."

"Sec. 304.
  1. Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the Commission may by rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the proper administration of this Act. The Commission may prescribe the manner and FERC Form in which such reports shall be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies*.10
"Sec. 309.
  1. The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and the time within which they shall be field..."

GENERAL PENALTIES

The Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).


FERC FORM NO.
1

REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER
IDENTIFICATION
01 Exact Legal Name of Respondent

Commonwealth Edison Company
02 Year/ Period of Report


End of:
2023
/
Q4
03 Previous Name and Date of Change (If name changed during year)

/
04 Address of Principal Office at End of Period (Street, City, State, Zip Code)

10 S. Dearborn Street, Chicago, Illinois 60603
05 Name of Contact Person

Steven J. Cichocki
06 Title of Contact Person

Director, Accounting
07 Address of Contact Person (Street, City, State, Zip Code)

Three Lincoln Center, Oakbrook Terrace, Illinois 60181-4260
08 Telephone of Contact Person, Including Area Code

(779) 231-1177
09 This Report is An Original / A Resubmission

(1)
An Original

(2)
A Resubmission
10 Date of Report (Mo, Da, Yr)

12/31/2023
Annual Corporate Officer Certification
The undersigned officer certifies that:

I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts.

01 Name

Joshua S. Levin
02 Title

SVP, CFO and Treasurer
03 Signature

Joshua S. Levin
04 Date Signed (Mo, Da, Yr)

03/29/2024
Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
LIST OF SCHEDULES (Electric Utility)

Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".

Line No.
Title of Schedule
(a)
Reference Page No.
(b)
Remarks
(c)
ScheduleIdentificationAbstract
Identification
1
ScheduleListOfSchedulesAbstract
List of Schedules
2
1
ScheduleGeneralInformationAbstract
General Information
101
2
ScheduleControlOverRespondentAbstract
Control Over Respondent
102
3
ScheduleCorporationsControlledByRespondentAbstract
Corporations Controlled by Respondent
103
4
ScheduleOfficersAbstract
Officers
104
5
ScheduleDirectorsAbstract
Directors
105
6
ScheduleInformationOnFormulaRatesAbstract
Information on Formula Rates
106
7
ScheduleImportantChangesDuringTheQuarterYearAbstract
Important Changes During the Year
108
8
ScheduleComparativeBalanceSheetAbstract
Comparative Balance Sheet
110
9
ScheduleStatementOfIncomeAbstract
Statement of Income for the Year
114
10
ScheduleRetainedEarningsAbstract
Statement of Retained Earnings for the Year
118
12
ScheduleStatementOfCashFlowsAbstract
Statement of Cash Flows
120
12
ScheduleNotesToFinancialStatementsAbstract
Notes to Financial Statements
122
13
ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract
Statement of Accum Other Comp Income, Comp Income, and Hedging Activities
122a
14
ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep
200
15
ScheduleNuclearFuelMaterialsAbstract
Nuclear Fuel Materials
202
N/A
16
ScheduleElectricPlantInServiceAbstract
Electric Plant in Service
204
17
ScheduleElectricPropertyLeasedToOthersAbstract
Electric Plant Leased to Others
213
N/A
18
ScheduleElectricPlantHeldForFutureUseAbstract
Electric Plant Held for Future Use
214
19
ScheduleConstructionWorkInProgressElectricAbstract
Construction Work in Progress-Electric
216
20
ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract
Accumulated Provision for Depreciation of Electric Utility Plant
219
21
ScheduleInvestmentsInSubsidiaryCompaniesAbstract
Investment of Subsidiary Companies
224
22
ScheduleMaterialsAndSuppliesAbstract
Materials and Supplies
227
23
ScheduleAllowanceInventoryAbstract
Allowances
228
N/A
24
ScheduleExtraordinaryPropertyLossesAbstract
Extraordinary Property Losses
230a
N/A
25
ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract
Unrecovered Plant and Regulatory Study Costs
230b
N/A
26
ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract
Transmission Service and Generation Interconnection Study Costs
231
27
ScheduleOtherRegulatoryAssetsAbstract
Other Regulatory Assets
232
28
ScheduleMiscellaneousDeferredDebitsAbstract
Miscellaneous Deferred Debits
233
29
ScheduleAccumulatedDeferredIncomeTaxesAbstract
Accumulated Deferred Income Taxes
234
30
ScheduleCapitalStockAbstract
Capital Stock
250
31
ScheduleOtherPaidInCapitalAbstract
Other Paid-in Capital
253
32
ScheduleCapitalStockExpenseAbstract
Capital Stock Expense
254b
33
ScheduleLongTermDebtAbstract
Long-Term Debt
256
34
ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract
Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax
261
35
ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract
Taxes Accrued, Prepaid and Charged During the Year
262
36
ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract
Accumulated Deferred Investment Tax Credits
266
37
ScheduleOtherDeferredCreditsAbstract
Other Deferred Credits
269
38
ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract
Accumulated Deferred Income Taxes-Accelerated Amortization Property
272
N/A
39
ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract
Accumulated Deferred Income Taxes-Other Property
274
40
ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract
Accumulated Deferred Income Taxes-Other
276
41
ScheduleOtherRegulatoryLiabilitiesAbstract
Other Regulatory Liabilities
278
42
ScheduleElectricOperatingRevenuesAbstract
Electric Operating Revenues
300
43
ScheduleRegionalTransmissionServiceRevenuesAbstract
Regional Transmission Service Revenues (Account 457.1)
302
N/A
44
ScheduleSalesOfElectricityByRateSchedulesAbstract
Sales of Electricity by Rate Schedules
304
45
ScheduleSalesForResaleAbstract
Sales for Resale
310
46
ScheduleElectricOperationsAndMaintenanceExpensesAbstract
Electric Operation and Maintenance Expenses
320
47
SchedulePurchasedPowerAbstract
Purchased Power
326
48
ScheduleTransmissionOfElectricityForOthersAbstract
Transmission of Electricity for Others
328
49
ScheduleTransmissionOfElectricityByIsoOrRtoAbstract
Transmission of Electricity by ISO/RTOs
331
N/A
50
ScheduleTransmissionOfElectricityByOthersAbstract
Transmission of Electricity by Others
332
51
ScheduleMiscellaneousGeneralExpensesAbstract
Miscellaneous General Expenses-Electric
335
52
ScheduleDepreciationDepletionAndAmortizationAbstract
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
336
53
ScheduleRegulatoryCommissionExpensesAbstract
Regulatory Commission Expenses
350
54
ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract
Research, Development and Demonstration Activities
352
55
ScheduleDistributionOfSalariesAndWagesAbstract
Distribution of Salaries and Wages
354
56
ScheduleCommonUtilityPlantAndExpensesAbstract
Common Utility Plant and Expenses
356
N/A
57
ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract
Amounts included in ISO/RTO Settlement Statements
397
58
SchedulePurchasesSalesOfAncillaryServicesAbstract
Purchase and Sale of Ancillary Services
398
59
ScheduleMonthlyTransmissionSystemPeakLoadAbstract
Monthly Transmission System Peak Load
400
60
ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract
Monthly ISO/RTO Transmission System Peak Load
400a
N/A
61
ScheduleElectricEnergyAccountAbstract
Electric Energy Account
401a
62
ScheduleMonthlyPeakAndOutputAbstract
Monthly Peaks and Output
401b
63
ScheduleSteamElectricGeneratingPlantStatisticsAbstract
Steam Electric Generating Plant Statistics
402
N/A
64
ScheduleHydroelectricGeneratingPlantStatisticsAbstract
Hydroelectric Generating Plant Statistics
406
N/A
65
SchedulePumpedStorageGeneratingPlantStatisticsAbstract
Pumped Storage Generating Plant Statistics
408
N/A
66
ScheduleGeneratingPlantStatisticsAbstract
Generating Plant Statistics Pages
410
N/A
66.1
ScheduleEnergyStorageOperationsLargePlantsAbstract
Energy Storage Operations (Large Plants)
414
N/A
66.2
ScheduleEnergyStorageOperationsSmallPlantsAbstract
Energy Storage Operations (Small Plants)
419
N/A
67
ScheduleTransmissionLineStatisticsAbstract
Transmission Line Statistics Pages
422
68
ScheduleTransmissionLinesAddedAbstract
Transmission Lines Added During Year
424
69
ScheduleSubstationsAbstract
Substations
426
70
ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract
Transactions with Associated (Affiliated) Companies
429
71
FootnoteDataAbstract
Footnote Data
450
StockholdersReportsAbstract
Stockholders' Reports (check appropriate box)
Stockholders' Reports Check appropriate box:

Two copies will be submitted

No annual report to stockholders is prepared


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
GENERAL INFORMATION
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept.

Steven J. Cichocki

Director, Accounting

Three Lincoln Center, Oakbrook Terrace, Illinois 60181-4260
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized.

State of Incorporation:
IL

Date of Incorporation:
1913-10-17

Incorporated Under Special Law:

3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased.

Not applicable.

(a) Name of Receiver or Trustee Holding Property of the Respondent:

(b) Date Receiver took Possession of Respondent Property:

(c) Authority by which the Receivership or Trusteeship was created:

(d) Date when possession by receiver or trustee ceased:
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated.

Electric utility services in the State of Illinois.
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements?
(1)
Yes

(2)
No


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.
Exelon Corporation (Exelon) indirectly owns 99.99% of ComEd's common stock through Exelon's consolidated subsidiary Exelon Energy Delivery, LLC.


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
CORPORATIONS CONTROLLED BY RESPONDENT
  1. Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote.
  2. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved.
  3. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests.
Definitions
  1. See the Uniform System of Accounts for a definition of control.
  2. Direct control is that which is exercised without interposition of an intermediary.
  3. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control.
  4. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party.
Line No.
NameOfCompanyControlledByRespondent
Name of Company Controlled
(a)
CompanyControlledByRespondentKindOfBusinessDescription
Kind of Business
(b)
VotingStockOwnedByRespondentPercentage
Percent Voting Stock Owned
(c)
FootnoteReferences
Footnote Ref.
(d)
1
Commonwealth Edison Company of Indiana, Inc.
Transmission of electricity
100
2
ComEd Financing III
Financing Trust
100
3
RITELine Illinois, LLC
Transmission of electricity
75
4
EdiSun, LLC
Development of solar panels
100


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
OFFICERS
  1. Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions.
  2. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made.
Line No.
OfficerTitle
Title
(a)
OfficerName
Name of Officer
(b)
OfficerSalary
Salary for Year
(c)
DateOfficerIncumbencyStarted
Date Started in Period
(d)
DateOfficerIncumbencyEnded
Date Ended in Period
(e)
1
Chief Executive Officer
Gil Quiniones
614,250
2
President and Chief Operating Officer
Terence R. Donnelly
500,737
2023-12-31
3
President and Chief Operating Officer
David Perez
420,000
2024-01-01
4
Senior Vice President, Distribution Operations
David Perez
356,540
2023-12-31
5
Senior Vice President, Chief Financial Officer and Treasurer
Elisabeth J. Graham
393,179
2023-08-08
6
Senior Vice President, Chief Financial Officer and Treasurer
Joshua Levin
386,250
2023-08-09
7
Senior Vice President, Governmental, Regulatory and External Affairs
Lewis Binswanger
404,400
8
Senior Vice President, Customer Operations and Chief Customer Officer
Melissa Washington
359,663
9
Senior Vice President and General Counsel
E. Glenn Rippie
368,524
10
Corporate Secretary
Katherine Smith
282,111
2023-12-31
11
Corporate Secretary
Gayle Littleton
676,000
2024-02-01


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
DIRECTORS
  1. Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), name and abbreviated titles of the directors who are officers of the respondent.
  2. Provide the principle place of business in column (b), designate members of the Executive Committee in column (c), and the Chairman of the Executive Committee in column (d).
Line No.
NameAndTitleOfDirector
Name (and Title) of Director
(a)
PrincipalBusinessAddress
Principal Business Address
(b)
MemberOfTheExecutiveCommittee
Member of the Executive Committee
(c)
ChairmanOfTheExecutiveCommittee
Chairman of the Executive Committee
(d)
1
Calvin G. Butler, Jr.
10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603
true
true
2
Gil Quiniones (Chief Executive Officer)
10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603
false
false
3
Ricardo Estrada
10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603
false
false
4
Zaldwaynaka Scott
10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603
false
false
5
Smita Shah
10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603
false
false


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
INFORMATION ON FORMULA RATES
Does the respondent have formula rates?
Yes

No
  1. Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate.
Line No.
RateScheduleTariffNumber
FERC Rate Schedule or Tariff Number
(a)
ProceedingDocketNumber
FERC Proceeding
(b)
1
Attachment H-13A of PJM of OATT
Docket No. ER07-583-000
2
Attachment H-13A of PJM of OATT - Revised
Docket No. ER10-1247-000
3
Attachment H-13A of PJM of OATT - Revised
Docket No. ER11-3577-000
4
Attachment H-13A of PJM of OATT - Revised
Docket No. ER12-1793-000
5
Attachment H-13A of PJM of OATT - Revised
Docket No. ER13-1391-000
6
Attachment H-13A of PJM of OATT - Revised
Docket No. ER14-1728-000


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)?
Yes

No
  1. If yes, provide a listing of such filings as contained on the Commission's eLibrary website.
Line No.
AccessionNumber
Accession No.
(a)
DocumentDate
Document Date / Filed Date
(b)
DocketNumber
Docket No.
(c)
DescriptionOfFiling
Description
(d)
RateScheduleTariffNumber
Formula Rate FERC Rate Schedule Number or Tariff Number
(e)
1
05/15/2008
ER08-963-000
Formula Rate Annual Update
H-13 PJM OATT
2
05/15/2009
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
3
05/14/2010
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
4
05/16/2011
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
5
05/15/2012
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
6
04/29/2013
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
7
04/16/2014
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
8
04/15/2015
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
9
05/19/2015
ER09-1145-000
Formula Rate Annual Update - Correction
H-13 PJM OATT
10
04/13/2016
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
11
04/13/2017
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
12
05/04/2018
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
13
05/10/2019
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
14
05/15/2020
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
15
04/16/2021
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
16
04/29/2022
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
17
05/12/2023
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: AccessionNumber
Included within the formula rate filings are references to certain information included within the FERC Form 1 pages.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
INFORMATION ON FORMULA RATES - Formula Rate Variances
  1. If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from amounts reported in the Form 1.
  2. The footnote should provide a narrative description explaining how the "rate" (or billing) was derived if different from the reported amount in the Form 1.
  3. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts.
  4. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote.
Line No.
PageNumberOfFormulaRateVariances
Page No(s).
(a)
ScheduleOfFormulaRateVariances
Schedule
(b)
ColumnOfFormulaRateVariances
Column
(c)
LineNumberOfFormulaRateVariances
Line No.
(d)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
IMPORTANT CHANGES DURING THE QUARTER/YEAR

Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears.

  1. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact.
  2. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization.
  3. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission.
  4. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization.
  5. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc.
  6. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee.
  7. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments.
  8. State the estimated annual effect and nature of any important wage scale changes during the year.
  9. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year.
  10. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Pages 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest.
  11. (Reserved.)
  12. If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page.
  13. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period.
  14. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.
1. None.
2. None.
3. None.
4. None.
5. None.
6. ComEd issues long-term debt under Orders by the Illinois Commerce Commission (ICC) approving ComEd’s securities. As of December 31, 2023, ComEd has New Money authority outstanding under Order 23-0492 totaling $2.0 billion and under Order 21-0540 totaling $368 million. On December 14, 2023, the ICC approved ComEd's request for $2.0 billion of New Money Authority, with an effective date of January 1, 2024, which will expire January 1, 2027.

ComEd meets its short-term liquidity requirements primarily through the issuance of commercial paper. As of December 31, 2023, ComEd had $202 million of outstanding commercial paper as well as $400 million outstanding on a 364-day short-term loan agreement expiring on May 7, 2024. ComEd's commercial paper borrowings are issued under the authority of FERC order Docket No. ES24-4-000 for up to $2.5 billion of short-term debt over the course of two years. ComEd's short-term financing authority expires on December 31, 2025.

As of December 31, 2023, ComEd had an effective shelf registration statement unlimited in amount, filed with the SEC, that is set to expire on August 3, 2025. As of February 21, 2024, Exelon Corporation filed with the SEC a post-effective amendment to its shelf registration statement. As a result of the post-effective amendment, Exelon Corporation amended the existing shelf and is authorized to issue $7,200 million in securities. ComEd is listed as a co-registrant on the post-effective amendment filed with the SEC on February 21, 2024, and has the ability to issue a portion of the authorized Exelon Corporation amount in debt securities. There were no changes made to the August 3, 2025 expiration date of the shelf registration statement as a result of the post-effective amendment. ComEd’s ability to sell securities off the shelf registration statement or to access the private placement markets will depend on a number of factors at the time of the proposed sale, including other required regulatory approvals, as applicable, ComEd’s current financial condition, its securities ratings and market conditions.

On January 3, 2023, ComEd entered into a purchase agreement of First Mortgage Bonds of $400 million and $575 million at 4.90% and 5.30% due on February 1, 2033 and February 1, 2053, respectively. The closing date of the issuance occurred on January 10, 2023. The $150 million balance on the 364-day term-loan was repaid on January 13, 2023 in conjunction with $400 million and $575 million First Mortgage Bond agreements being entered into.

Refer to Pages 122-123, Notes to Financial Statements: Note 10 — Debt and Credit Agreements section for subsequent changes that occurred in 2024.
7. None.
8. A base pay increase pool of 3% and 4% was distributed among exempt and non-exempt, non-represented employees on March 1, 2024 and March 1, 2023, respectively. Select market adjustments were made in March 2023 to ensure market competitiveness to aid in retaining talent in a hyper competitive market.
9. Refer to Pages 122-123, Notes to Financial Statements: Note 2 — Regulatory Matters and Note 12 - Commitments and Contingencies “Litigation and Regulatory Matters” section.
10. None.
See Officers page (Page 104) and Directors page (Page 105) for details concerning changes in the respondent's officers during 2023.
14. None.


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.
Title of Account
(a)
Ref. Page No.
(b)
Current Year End of Quarter/Year Balance
(c)
Prior Year End Balance 12/31
(d)
1
UtilityPlantAbstract
UTILITY PLANT
2
UtilityPlant
Utility Plant (101-106, 114)
200
40,315,002,584
38,410,366,342
3
ConstructionWorkInProgress
Construction Work in Progress (107)
200
1,395,544,738
1,197,396,998
4
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Enter Total of lines 2 and 3)
41,710,547,322
39,607,763,340
5
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
(Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)
200
11,713,097,084
11,104,020,269
6
UtilityPlantNet
Net Utility Plant (Enter Total of line 4 less 5)
29,997,450,238
28,503,743,071
7
NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication
Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)
202
8
NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly
Nuclear Fuel Materials and Assemblies-Stock Account (120.2)
9
NuclearFuelAssembliesInReactorMajorOnly
Nuclear Fuel Assemblies in Reactor (120.3)
10
SpentNuclearFuelMajorOnly
Spent Nuclear Fuel (120.4)
11
NuclearFuelUnderCapitalLeases
Nuclear Fuel Under Capital Leases (120.6)
12
AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies
(Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)
202
13
NuclearFuelNet
Net Nuclear Fuel (Enter Total of lines 7-11 less 12)
14
UtilityPlantAndNuclearFuelNet
Net Utility Plant (Enter Total of lines 6 and 13)
29,997,450,238
28,503,743,071
15
OtherElectricPlantAdjustments
Utility Plant Adjustments (116)
16
GasStoredUndergroundNoncurrent
Gas Stored Underground - Noncurrent (117)
17
OtherPropertyAndInvestmentsAbstract
OTHER PROPERTY AND INVESTMENTS
18
NonutilityProperty
Nonutility Property (121)
9,697,258
9,697,258
19
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty
(Less) Accum. Prov. for Depr. and Amort. (122)
1,905,868
1,875,760
20
InvestmentInAssociatedCompanies
Investments in Associated Companies (123)
21
InvestmentInSubsidiaryCompanies
Investment in Subsidiary Companies (123.1)
224
102,288,128
96,806,785
23
NoncurrentPortionOfAllowances
Noncurrent Portion of Allowances
228
24
OtherInvestments
Other Investments (124)
37,334
29,236
25
SinkingFunds
Sinking Funds (125)
26
DepreciationFund
Depreciation Fund (126)
27
AmortizationFundFederal
Amortization Fund - Federal (127)
28
OtherSpecialFunds
Other Special Funds (128)
29
SpecialFunds
Special Funds (Non Major Only) (129)
30
DerivativeInstrumentAssetsLongTerm
Long-Term Portion of Derivative Assets (175)
31
DerivativeInstrumentAssetsHedgesLongTerm
Long-Term Portion of Derivative Assets - Hedges (176)
32
OtherPropertyAndInvestments
TOTAL Other Property and Investments (Lines 18-21 and 23-31)
110,116,852
104,657,519
33
CurrentAndAccruedAssetsAbstract
CURRENT AND ACCRUED ASSETS
34
CashAndWorkingFunds
Cash and Working Funds (Non-major Only) (130)
35
Cash
Cash (131)
45,643,539
10,668,984
36
SpecialDeposits
Special Deposits (132-134)
401,566,878
327,463,034
37
WorkingFunds
Working Fund (135)
38
TemporaryCashInvestments
Temporary Cash Investments (136)
23,989,634
23,969,852
39
NotesReceivable
Notes Receivable (141)
40
CustomerAccountsReceivable
Customer Accounts Receivable (142)
508,571,219
335,351,787
41
OtherAccountsReceivable
Other Accounts Receivable (143)
242,277,627
441,200,349
42
AccumulatedProvisionForUncollectibleAccountsCredit
(Less) Accum. Prov. for Uncollectible Acct.-Credit (144)
86,250,851
76,000,066
43
NotesReceivableFromAssociatedCompanies
Notes Receivable from Associated Companies (145)
44
AccountsReceivableFromAssociatedCompanies
Accounts Receivable from Assoc. Companies (146)
70,491
505,854
45
FuelStock
Fuel Stock (151)
227
46
FuelStockExpensesUndistributed
Fuel Stock Expenses Undistributed (152)
227
47
Residuals
Residuals (Elec) and Extracted Products (153)
227
48
PlantMaterialsAndOperatingSupplies
Plant Materials and Operating Supplies (154)
227
285,561,287
195,014,751
49
Merchandise
Merchandise (155)
227
50
OtherMaterialsAndSupplies
Other Materials and Supplies (156)
227
51
NuclearMaterialsHeldForSale
Nuclear Materials Held for Sale (157)
202/227
52
AllowanceInventoryAndWithheld
Allowances (158.1 and 158.2)
228
53
NoncurrentPortionOfAllowances
(Less) Noncurrent Portion of Allowances
228
54
StoresExpenseUndistributed
Stores Expense Undistributed (163)
227
55
GasStoredCurrent
Gas Stored Underground - Current (164.1)
56
LiquefiedNaturalGasStoredAndHeldForProcessing
Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57
Prepayments
Prepayments (165)
102,590,569
77,239,527
58
AdvancesForGas
Advances for Gas (166-167)
59
InterestAndDividendsReceivable
Interest and Dividends Receivable (171)
10,540
5,688
60
RentsReceivable
Rents Receivable (172)
61
AccruedUtilityRevenues
Accrued Utility Revenues (173)
351,134,876
222,847,466
62
MiscellaneousCurrentAndAccruedAssets
Miscellaneous Current and Accrued Assets (174)
4,318,888
3,595,441
63
DerivativeInstrumentAssets
Derivative Instrument Assets (175)
64
DerivativeInstrumentAssetsLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets (175)
65
DerivativeInstrumentAssetsHedges
Derivative Instrument Assets - Hedges (176)
66
DerivativeInstrumentAssetsHedgesLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67
CurrentAndAccruedAssets
Total Current and Accrued Assets (Lines 34 through 66)
1,879,484,697
1,561,862,667
68
DeferredDebitsAbstract
DEFERRED DEBITS
69
UnamortizedDebtExpense
Unamortized Debt Expenses (181)
99,782,409
93,089,140
70
ExtraordinaryPropertyLosses
Extraordinary Property Losses (182.1)
230a
71
UnrecoveredPlantAndRegulatoryStudyCosts
Unrecovered Plant and Regulatory Study Costs (182.2)
230b
72
OtherRegulatoryAssets
Other Regulatory Assets (182.3)
232
4,396,564,225
3,424,287,027
73
PreliminarySurveyAndInvestigationCharges
Prelim. Survey and Investigation Charges (Electric) (183)
74
PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges
Preliminary Natural Gas Survey and Investigation Charges 183.1)
75
OtherPreliminarySurveyAndInvestigationCharges
Other Preliminary Survey and Investigation Charges (183.2)
76
ClearingAccounts
Clearing Accounts (184)
325
77
TemporaryFacilities
Temporary Facilities (185)
78
MiscellaneousDeferredDebits
Miscellaneous Deferred Debits (186)
233
4,997,467,960
4,423,330,171
79
DeferredLossesFromDispositionOfUtilityPlant
Def. Losses from Disposition of Utility Plt. (187)
80
ResearchDevelopmentAndDemonstrationExpenditures
Research, Devel. and Demonstration Expend. (188)
352
81
UnamortizedLossOnReacquiredDebt
Unamortized Loss on Reaquired Debt (189)
16,424,002
18,008,377
82
AccumulatedDeferredIncomeTaxes
Accumulated Deferred Income Taxes (190)
234
1,006,863,343
268,238,892
83
UnrecoveredPurchasedGasCosts
Unrecovered Purchased Gas Costs (191)
84
DeferredDebits
Total Deferred Debits (lines 69 through 83)
10,517,102,264
8,226,953,607
85
AssetsAndOtherDebits
TOTAL ASSETS (lines 14-16, 32, 67, and 84)
42,504,154,051
38,397,216,864


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.
Title of Account
(a)
Ref. Page No.
(b)
Current Year End of Quarter/Year Balance
(c)
Prior Year End Balance 12/31
(d)
1
ProprietaryCapitalAbstract
PROPRIETARY CAPITAL
2
CommonStockIssued
Common Stock Issued (201)
250
1,587,297,032
1,587,296,970
3
PreferredStockIssued
Preferred Stock Issued (204)
250
4
CapitalStockSubscribed
Capital Stock Subscribed (202, 205)
5
StockLiabilityForConversion
Stock Liability for Conversion (203, 206)
6
PremiumOnCapitalStock
Premium on Capital Stock (207)
5,020,104,944
5,020,104,795
7
OtherPaidInCapital
Other Paid-In Capital (208-211)
253
5,388,756,067
4,733,210,990
8
InstallmentsReceivedOnCapitalStock
Installments Received on Capital Stock (212)
252
9
DiscountOnCapitalStock
(Less) Discount on Capital Stock (213)
254
10
CapitalStockExpense
(Less) Capital Stock Expense (214)
254b
6,942,925
6,942,925
11
RetainedEarnings
Retained Earnings (215, 215.1, 216)
118
2,327,289,291
1,983,697,102
12
UnappropriatedUndistributedSubsidiaryEarnings
Unappropriated Undistributed Subsidiary Earnings (216.1)
118
51,743,312
46,618,704
13
ReacquiredCapitalStock
(Less) Reacquired Capital Stock (217)
250
14
NoncorporateProprietorship
Noncorporate Proprietorship (Non-major only) (218)
15
AccumulatedOtherComprehensiveIncome
Accumulated Other Comprehensive Income (219)
122(a)(b)
16
ProprietaryCapital
Total Proprietary Capital (lines 2 through 15)
14,368,247,721
13,363,985,636
17
LongTermDebtAbstract
LONG-TERM DEBT
18
Bonds
Bonds (221)
256
11,603,600,000
10,628,600,000
19
ReacquiredBonds
(Less) Reacquired Bonds (222)
256
20
AdvancesFromAssociatedCompanies
Advances from Associated Companies (223)
256
206,186,000
206,186,000
21
OtherLongTermDebt
Other Long-Term Debt (224)
256
22
UnamortizedPremiumOnLongTermDebt
Unamortized Premium on Long-Term Debt (225)
23
UnamortizedDiscountOnLongTermDebtDebit
(Less) Unamortized Discount on Long-Term Debt-Debit (226)
28,371,972
27,228,308
24
LongTermDebt
Total Long-Term Debt (lines 18 through 23)
11,781,414,028
10,807,557,692
25
OtherNoncurrentLiabilitiesAbstract
OTHER NONCURRENT LIABILITIES
26
ObligationsUnderCapitalLeaseNoncurrent
Obligations Under Capital Leases - Noncurrent (227)
7,532,029
7,582,639
27
AccumulatedProvisionForPropertyInsurance
Accumulated Provision for Property Insurance (228.1)
28
AccumulatedProvisionForInjuriesAndDamages
Accumulated Provision for Injuries and Damages (228.2)
81,424,515
64,506,591
29
AccumulatedProvisionForPensionsAndBenefits
Accumulated Provision for Pensions and Benefits (228.3)
197,131,365
201,364,987
30
AccumulatedMiscellaneousOperatingProvisions
Accumulated Miscellaneous Operating Provisions (228.4)
302,552,734
324,697,427
31
AccumulatedProvisionForRateRefunds
Accumulated Provision for Rate Refunds (229)
7,188,191
32
LongTermPortionOfDerivativeInstrumentLiabilities
Long-Term Portion of Derivative Instrument Liabilities
33
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
Long-Term Portion of Derivative Instrument Liabilities - Hedges
34
AssetRetirementObligations
Asset Retirement Obligations (230)
151,156,355
150,443,983
35
OtherNoncurrentLiabilities
Total Other Noncurrent Liabilities (lines 26 through 34)
746,985,189
748,595,627
36
CurrentAndAccruedLiabilitiesAbstract
CURRENT AND ACCRUED LIABILITIES
37
NotesPayable
Notes Payable (231)
601,937,997
576,854,300
38
AccountsPayable
Accounts Payable (232)
828,813,132
845,896,275
39
NotesPayableToAssociatedCompanies
Notes Payable to Associated Companies (233)
40
AccountsPayableToAssociatedCompanies
Accounts Payable to Associated Companies (234)
72,879,463
73,723,918
41
CustomerDeposits
Customer Deposits (235)
118,238,326
107,584,029
42
TaxesAccrued
Taxes Accrued (236)
262
211,291,922
96,153,710
43
InterestAccrued
Interest Accrued (237)
149,033,092
125,208,072
44
DividendsDeclared
Dividends Declared (238)
45
MaturedLongTermDebt
Matured Long-Term Debt (239)
46
MaturedInterest
Matured Interest (240)
47
TaxCollectionsPayable
Tax Collections Payable (241)
31,397,970
12,419,905
48
MiscellaneousCurrentAndAccruedLiabilities
Miscellaneous Current and Accrued Liabilities (242)
440,174,247
519,370,198
49
ObligationsUnderCapitalLeasesCurrent
Obligations Under Capital Leases-Current (243)
70,210
64,620
50
DerivativesInstrumentLiabilities
Derivative Instrument Liabilities (244)
51
LongTermPortionOfDerivativeInstrumentLiabilities
(Less) Long-Term Portion of Derivative Instrument Liabilities
52
DerivativeInstrumentLiabilitiesHedges
Derivative Instrument Liabilities - Hedges (245)
53
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
(Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54
CurrentAndAccruedLiabilities
Total Current and Accrued Liabilities (lines 37 through 53)
2,453,836,359
2,357,275,027
55
DeferredCreditsAbstract
DEFERRED CREDITS
56
CustomerAdvancesForConstruction
Customer Advances for Construction (252)
455,558,952
239,396,349
57
AccumulatedDeferredInvestmentTaxCredits
Accumulated Deferred Investment Tax Credits (255)
266
6,810,301
7,660,602
58
DeferredGainsFromDispositionOfUtilityPlant
Deferred Gains from Disposition of Utility Plant (256)
59
OtherDeferredCredits
Other Deferred Credits (253)
269
120,260,137
93,605,831
60
OtherRegulatoryLiabilities
Other Regulatory Liabilities (254)
278
6,253,543,172
5,499,295,974
61
UnamortizedGainOnReacquiredDebt
Unamortized Gain on Reacquired Debt (257)
62
AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty
Accum. Deferred Income Taxes-Accel. Amort.(281)
272
63
AccumulatedDeferredIncomeTaxesOtherProperty
Accum. Deferred Income Taxes-Other Property (282)
4,971,124,063
4,272,205,881
64
AccumulatedDeferredIncomeTaxesOther
Accum. Deferred Income Taxes-Other (283)
1,346,374,129
1,007,638,245
65
DeferredCredits
Total Deferred Credits (lines 56 through 64)
13,153,670,754
11,119,802,882
66
LiabilitiesAndOtherCredits
TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)
42,504,154,051
38,397,216,864


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
STATEMENT OF INCOME

Quarterly

  1. Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only.
  2. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year.
  3. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter.
  4. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter.
  5. If additional columns are needed, place them in a footnote.

Annual or Quarterly if applicable

  1. Do not report fourth quarter data in columns (e) and (f)
  2. Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals.
  3. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above.
  4. Use page 122 for important notes regarding the statement of income for any account thereof.
  5. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases.
  6. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts.
  7. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122.
  8. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes.
  9. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports.
  10. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.
Title of Account
(a)
(Ref.) Page No.
(b)
Total Current Year to Date Balance for Quarter/Year
(c)
Total Prior Year to Date Balance for Quarter/Year
(d)
Current 3 Months Ended - Quarterly Only - No 4th Quarter
(e)
Prior 3 Months Ended - Quarterly Only - No 4th Quarter
(f)
Electric Utility Current Year to Date (in dollars)
(g)
Electric Utility Previous Year to Date (in dollars)
(h)
Gas Utiity Current Year to Date (in dollars)
(i)
Gas Utility Previous Year to Date (in dollars)
(j)
Other Utility Current Year to Date (in dollars)
(k)
Other Utility Previous Year to Date (in dollars)
(l)
1
UtilityOperatingIncomeAbstract
UTILITY OPERATING INCOME
2
OperatingRevenues
Operating Revenues (400)
300
7,847,450,785
5,797,975,458
7,847,450,785
5,797,975,458
3
OperatingExpensesAbstract
Operating Expenses
4
OperationExpense
Operation Expenses (401)
320
3,832,950,659
2,092,928,234
3,832,950,659
2,092,928,234
5
MaintenanceExpense
Maintenance Expenses (402)
320
459,380,558
444,212,205
459,380,558
444,212,205
6
DepreciationExpense
Depreciation Expense (403)
336
1,006,052,806
935,016,340
1,006,052,806
935,016,340
7
DepreciationExpenseForAssetRetirementCosts
Depreciation Expense for Asset Retirement Costs (403.1)
336
1,858,923
2,103,665
1,858,923
2,103,665
8
AmortizationAndDepletionOfUtilityPlant
Amort. & Depl. of Utility Plant (404-405)
336
100,660,161
102,491,635
100,660,161
102,491,635
9
AmortizationOfElectricPlantAcquisitionAdjustments
Amort. of Utility Plant Acq. Adj. (406)
336
10
AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts
Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)
11
AmortizationOfConversionExpenses
Amort. of Conversion Expenses (407.2)
12
RegulatoryDebits
Regulatory Debits (407.3)
305,964,625
311,737,491
305,964,625
311,737,491
13
RegulatoryCredits
(Less) Regulatory Credits (407.4)
(a)
62,177,236
(b)
65,912,068
62,177,236
65,912,068
14
TaxesOtherThanIncomeTaxesUtilityOperatingIncome
Taxes Other Than Income Taxes (408.1)
262
367,534,329
372,384,738
367,534,329
372,384,738
15
IncomeTaxesOperatingIncome
Income Taxes - Federal (409.1)
262
129,557,732
36,318,594
129,557,732
36,318,594
16
IncomeTaxesUtilityOperatingIncomeOther
Income Taxes - Other (409.1)
262
11,432,424
1,541,100
11,432,424
1,541,100
17
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome
Provision for Deferred Income Taxes (410.1)
234, 272
592,520,153
518,448,124
592,520,153
518,448,124
18
ProvisionForDeferredIncomeTaxesCreditOperatingIncome
(Less) Provision for Deferred Income Taxes-Cr. (411.1)
234, 272
399,639,434
277,388,074
399,639,434
277,388,074
19
InvestmentTaxCreditAdjustments
Investment Tax Credit Adj. - Net (411.4)
266
1,218,203
1,228,182
1,218,203
1,228,182
20
GainsFromDispositionOfPlant
(Less) Gains from Disp. of Utility Plant (411.6)
21
LossesFromDispositionOfServiceCompanyPlant
Losses from Disp. of Utility Plant (411.7)
22
GainsFromDispositionOfAllowances
(Less) Gains from Disposition of Allowances (411.8)
23
LossesFromDispositionOfAllowances
Losses from Disposition of Allowances (411.9)
24
AccretionExpense
Accretion Expense (411.10)
51,297
54,610
51,297
54,610
25
UtilityOperatingExpenses
TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)
6,322,063,946
4,469,626,212
6,322,063,946
4,469,626,212
27
NetUtilityOperatingIncome
Net Util Oper Inc (Enter Tot line 2 less 25)
1,525,386,839
1,328,349,246
1,525,386,839
1,328,349,246
28
OtherIncomeAndDeductionsAbstract
Other Income and Deductions
29
OtherIncomeAbstract
Other Income
30
NonutilityOperatingIncomeAbstract
Nonutilty Operating Income
31
RevenuesFromMerchandisingJobbingAndContractWork
Revenues From Merchandising, Jobbing and Contract Work (415)
22,794,716
16,852,398
32
CostsAndExpensesOfMerchandisingJobbingAndContractWork
(Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)
22,319,615
17,820,920
33
RevenuesFromNonutilityOperations
Revenues From Nonutility Operations (417)
34
ExpensesOfNonutilityOperations
(Less) Expenses of Nonutility Operations (417.1)
35
NonoperatingRentalIncome
Nonoperating Rental Income (418)
36
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings of Subsidiary Companies (418.1)
119
5,517,419
5,487,941
37
InterestAndDividendIncome
Interest and Dividend Income (419)
22,029,291
5,148,088
38
AllowanceForOtherFundsUsedDuringConstruction
Allowance for Other Funds Used During Construction (419.1)
33,462,076
34,825,019
39
MiscellaneousNonoperatingIncome
Miscellaneous Nonoperating Income (421)
17,817,710
15,187,541
40
GainOnDispositionOfProperty
Gain on Disposition of Property (421.1)
41
OtherIncome
TOTAL Other Income (Enter Total of lines 31 thru 40)
79,301,597
59,680,067
42
OtherIncomeDeductionsAbstract
Other Income Deductions
43
LossOnDispositionOfProperty
Loss on Disposition of Property (421.2)
1,777,495
44
MiscellaneousAmortization
Miscellaneous Amortization (425)
1,027
45
Donations
Donations (426.1)
5,905,354
15,247,336
46
LifeInsurance
Life Insurance (426.2)
8,098
10,815
47
Penalties
Penalties (426.3)
1,168,760
78,786
48
ExpendituresForCertainCivicPoliticalAndRelatedActivities
Exp. for Certain Civic, Political & Related Activities (426.4)
5,200,212
4,816,874
49
OtherDeductions
Other Deductions (426.5)
16,614,085
45,482,685
50
OtherIncomeDeductions
TOTAL Other Income Deductions (Total of lines 43 thru 49)
28,880,313
67,415,018
51
TaxesApplicableToOtherIncomeAndDeductionsAbstract
Taxes Applic. to Other Income and Deductions
52
TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions
Taxes Other Than Income Taxes (408.2)
262
956,149
1,129,890
53
IncomeTaxesFederal
Income Taxes-Federal (409.2)
262
6,753,836
7,922,820
54
IncomeTaxesOther
Income Taxes-Other (409.2)
262
1,295,297
3,960,367
55
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions
Provision for Deferred Inc. Taxes (410.2)
234, 272
56
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions
(Less) Provision for Deferred Income Taxes-Cr. (411.2)
234, 272
4,162,560
57
InvestmentTaxCreditAdjustmentsNonutilityOperations
Investment Tax Credit Adj.-Net (411.5)
58
InvestmentTaxCredits
(Less) Investment Tax Credits (420)
59
TaxesOnOtherIncomeAndDeductions
TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)
4,842,722
10,753,297
60
NetOtherIncomeAndDeductions
Net Other Income and Deductions (Total of lines 41, 50, 59)
45,578,562
3,018,346
61
InterestChargesAbstract
Interest Charges
62
InterestOnLongTermDebt
Interest on Long-Term Debt (427)
457,291,632
402,964,756
63
AmortizationOfDebtDiscountAndExpense
Amort. of Debt Disc. and Expense (428)
7,063,111
5,627,073
64
AmortizationOfLossOnReacquiredDebt
Amortization of Loss on Reaquired Debt (428.1)
1,584,375
1,584,375
65
AmortizationOfPremiumOnDebtCredit
(Less) Amort. of Premium on Debt-Credit (429)
66
AmortizationOfGainOnReacquiredDebtCredit
(Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67
InterestOnDebtToAssociatedCompanies
Interest on Debt to Assoc. Companies (430)
13,092,811
13,092,811
68
OtherInterestExpense
Other Interest Expense (431)
36,332,711
9,315,763
69
AllowanceForBorrowedFundsUsedDuringConstructionCredit
(Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)
38,477,582
18,394,231
70
NetInterestCharges
Net Interest Charges (Total of lines 62 thru 69)
476,887,058
414,190,547
71
IncomeBeforeExtraordinaryItems
Income Before Extraordinary Items (Total of lines 27, 60 and 70)
1,094,078,343
917,177,045
72
ExtraordinaryItemsAbstract
Extraordinary Items
73
ExtraordinaryIncome
Extraordinary Income (434)
74
ExtraordinaryDeductions
(Less) Extraordinary Deductions (435)
75
NetExtraordinaryItems
Net Extraordinary Items (Total of line 73 less line 74)
76
IncomeTaxesExtraordinaryItems
Income Taxes-Federal and Other (409.3)
262
77
ExtraordinaryItemsAfterTaxes
Extraordinary Items After Taxes (line 75 less line 76)
78
NetIncomeLoss
Net Income (Total of line 71 and 77)
1,094,078,343
917,177,045


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: RegulatoryCredits
Refer to Note 2 - Regulatory Matters of the Notes to Financial Statements located on page 122-123.
(b) Concept: RegulatoryCredits
Refer to Note 2 - Regulatory Matters of the Notes to Financial Statements located on page 122-123.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report


End of:
2023
/
Q4
STATEMENT OF RETAINED EARNINGS
  1. Do not report Lines 49-53 on the quarterly report.
  2. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year.
  3. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b).
  4. State the purpose and amount for each reservation or appropriation of retained earnings.
  5. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order.
  6. Show dividends for each class and series of capital stock.
  7. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings.
  8. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated.
  9. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No.
Item
(a)
Contra Primary Account Affected
(b)
Current Quarter/Year Year to Date Balance
(c)
Previous Quarter/Year Year to Date Balance
(d)
UnappropriatedRetainedEarningsAbstract
UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1
UnappropriatedRetainedEarnings
Balance-Beginning of Period
1,684,177,676
1,679,082,546
2
ChangesAbstract
Changes
3
AdjustmentsToRetainedEarningsAbstract
Adjustments to Retained Earnings (Account 439)
4
AdjustmentsToRetainedEarningsCreditAbstract
Adjustments to Retained Earnings Credit
9
AdjustmentsToRetainedEarningsCredit
TOTAL Credits to Retained Earnings (Acct. 439)
10
AdjustmentsToRetainedEarningsDebitAbstract
Adjustments to Retained Earnings Debit
15
AdjustmentsToRetainedEarningsDebit
TOTAL Debits to Retained Earnings (Acct. 439)
16
BalanceTransferredFromIncome
Balance Transferred from Income (Account 433 less Account 418.1)
1,088,560,924
911,689,104
17
AppropriationsOfRetainedEarningsAbstract
Appropriations of Retained Earnings (Acct. 436)
17.1
AppropriationsOfRetainedEarnings
Transfer to appropriated retained earnings for payment of future dividends
1,094,078,343
917,177,045
22
AppropriationsOfRetainedEarnings
TOTAL Appropriations of Retained Earnings (Acct. 436)
1,094,078,343
917,177,045
23
DividendsDeclaredPreferredStockAbstract
Dividends Declared-Preferred Stock (Account 437)
29
DividendsDeclaredPreferredStock
TOTAL Dividends Declared-Preferred Stock (Acct. 437)
30
DividendsDeclaredCommonStockAbstract
Dividends Declared-Common Stock (Account 438)
36
DividendsDeclaredCommonStock
TOTAL Dividends Declared-Common Stock (Acct. 438)
37
TransfersFromUnappropriatedUndistributedSubsidiaryEarnings
Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings
392,811
392,811
38
UnappropriatedRetainedEarnings
Balance - End of Period (Total 1,9,15,16,22,29,36,37)
1,689,302,284
1,684,177,676
39
AppropriatedRetainedEarningsAbstract
APPROPRIATED RETAINED EARNINGS (Account 215)
39.1
AppropriatedRetainedEarnings
Balance - Beginning of Year (Debit or Credit)
3,667,874,778
3,328,695,871
39.2
AppropriatedRetainedEarnings
Appropriations of retained earnings for future dividend payments
1,094,078,343
917,177,045
39.3
AppropriatedRetainedEarnings
Dividends declared
745,361,546
577,998,138
39.4
AppropriatedRetainedEarnings
Tax Adjustment for FIN48
45
AppropriatedRetainedEarnings
TOTAL Appropriated Retained Earnings (Account 215)
4,016,591,575
3,667,874,778
AppropriatedRetainedEarningsAmortizationReserveFederalAbstract
APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46
AppropriatedRetainedEarningsAmortizationReserveFederal
TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)
47
AppropriatedRetainedEarningsIncludingReserveAmortization
TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)
4,016,591,575
3,667,874,778
48
RetainedEarnings
TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)
2,327,289,291
1,983,697,102
UnappropriatedUndistributedSubsidiaryEarningsAbstract
UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49
UnappropriatedUndistributedSubsidiaryEarnings
Balance-Beginning of Year (Debit or Credit)
46,618,704
41,523,574
50
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings for Year (Credit) (Account 418.1)
5,517,419
5,487,941
51
DividendsReceived
(Less) Dividends Received (Debit)
392,811
392,811
52
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits
TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
53
UnappropriatedUndistributedSubsidiaryEarnings
Balance-End of Year (Total lines 49 thru 52)
51,743,312
46,618,704


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
STATEMENT OF CASH FLOWS
  1. Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc.
  2. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet.
  3. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid.
  4. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.
Description (See Instructions No.1 for explanation of codes)
(a)
Current Year to Date Quarter/Year
(b)
Previous Year to Date Quarter/Year
(c)
1
NetCashFlowFromOperatingActivitiesAbstract
Net Cash Flow from Operating Activities
2
NetIncomeLoss
Net Income (Line 78(c) on page 117)
1,094,078,343
917,177,045
3
NoncashChargesCreditsToIncomeAbstract
Noncash Charges (Credits) to Income:
4
DepreciationAndDepletion
Depreciation and Depletion
1,106,846,515
1,037,686,039
5
NoncashAdjustmentsToCashFlowsFromOperatingActivities
Amortization of (Specify) (footnote details)
5.1
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Amortization of Regulatory Debits
307,690,000
291,668,796
8
DeferredIncomeTaxesNet
Deferred Income Taxes (Net)
188,718,159
241,060,050
9
InvestmentTaxCreditAdjustmentsNet
Investment Tax Credit Adjustment (Net)
1,218,203
1,228,182
10
NetIncreaseDecreaseInReceivablesOperatingActivities
Net (Increase) Decrease in Receivables
91,686,824
139,101,460
11
NetIncreaseDecreaseInInventoryOperatingActivities
Net (Increase) Decrease in Inventory
82,594,953
25,147,249
12
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Net (Increase) Decrease in Allowances Inventory
13
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
149,791,921
211,019,267
14
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Net (Increase) Decrease in Other Regulatory Assets
1,203,735,116
1,602,031,591
15
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities
Net Increase (Decrease) in Other Regulatory Liabilities
566,474,926
293,922,175
16
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities
(Less) Allowance for Other Funds Used During Construction
33,462,076
34,825,019
17
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities
(Less) Undistributed Earnings from Subsidiary Companies
5,517,419
5,487,941
18
OtherAdjustmentsToCashFlowsFromOperatingActivities
Other (provide details in footnote):
18.1
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other (provide details in footnote):
(a)
263,962,518
(d)
149,805,506
22
NetCashFlowFromOperatingActivities
Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)
1,731,422,755
1,034,906,424
24
CashFlowsFromInvestmentActivitiesAbstract
Cash Flows from Investment Activities:
25
ConstructionAndAcquisitionOfPlantIncludingLandAbstract
Construction and Acquisition of Plant (including land):
26
GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Gross Additions to Utility Plant (less nuclear fuel)
2,674,451,724
2,576,796,527
27
GrossAdditionsToNuclearFuelInvestingActivities
Gross Additions to Nuclear Fuel
28
GrossAdditionsToCommonUtilityPlantInvestingActivities
Gross Additions to Common Utility Plant
29
GrossAdditionsToNonutilityPlantInvestingActivities
Gross Additions to Nonutility Plant
30
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
(Less) Allowance for Other Funds Used During Construction
33,462,076
34,825,019
31
OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Other (provide details in footnote):
31.1
OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription
Other (provide details in footnote):
34
CashOutflowsForPlant
Cash Outflows for Plant (Total of lines 26 thru 33)
2,640,989,648
2,541,971,508
36
AcquisitionOfOtherNoncurrentAssets
Acquisition of Other Noncurrent Assets (d)
37
ProceedsFromDisposalOfNoncurrentAssets
Proceeds from Disposal of Noncurrent Assets (d)
9,756,179
9,262,172
39
InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Investments in and Advances to Assoc. and Subsidiary Companies
356,735
801,539
40
ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies
Contributions and Advances from Assoc. and Subsidiary Companies
392,811
392,811
41
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract
Disposition of Investments in (and Advances to)
42
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
44
PurchaseOfInvestmentSecurities
Purchase of Investment Securities (a)
45
ProceedsFromSalesOfInvestmentSecurities
Proceeds from Sales of Investment Securities (a)
46
LoansMadeOrPurchased
Loans Made or Purchased
47
CollectionsOnLoans
Collections on Loans
49
NetIncreaseDecreaseInReceivablesInvestingActivities
Net (Increase) Decrease in Receivables
50
NetIncreaseDecreaseInInventoryInvestingActivities
Net (Increase) Decrease in Inventory
51
NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities
Net (Increase) Decrease in Allowances Held for Speculation
52
NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
53
OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other (provide details in footnote):
53.1
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Other (provide details in footnote):
(b)
38,332,264
(e)
26,056,097
57
CashFlowsProvidedFromUsedInInvestmentActivities
Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)
2,592,865,129
2,507,061,967
59
CashFlowsFromFinancingActivitiesAbstract
Cash Flows from Financing Activities:
60
ProceedsFromIssuanceAbstract
Proceeds from Issuance of:
61
ProceedsFromIssuanceOfLongTermDebtFinancingActivities
Long-Term Debt (b)
975,000,000
750,000,000
62
ProceedsFromIssuanceOfPreferredStockFinancingActivities
Preferred Stock
63
ProceedsFromIssuanceOfCommonStockFinancingActivities
Common Stock
64
OtherAdjustmentsToCashFlowsFromFinancingActivities
Other (provide details in footnote):
64.1
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription
Other (provide details in footnote):
66
NetIncreaseInShortTermDebt
Net Increase in Short-Term Debt (c)
25,083,697
576,854,300
67
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other (provide details in footnote):
67.1
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other (provide details in footnote):
67.2
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Debt Issuance Costs
13,830,728
11,712,478
70
CashProvidedByOutsideSources
Cash Provided by Outside Sources (Total 61 thru 69)
986,252,969
1,315,141,822
72
PaymentsForRetirementAbstract
Payments for Retirement of:
73
PaymentsForRetirementOfLongTermDebtFinancingActivities
Long-term Debt (b)
74
PaymentsForRetirementOfPreferredStockFinancingActivities
Preferred Stock
75
PaymentsForRetirementOfCommonStockFinancingActivities
Common Stock
12,583,145
926,233
76
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other (provide details in footnote):
76.1
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Other (provide details in footnote):
(c)
642,962,143
(f)
669,000,000
76.2
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Bond Issuance Costs
78
NetDecreaseInShortTermDebt
Net Decrease in Short-Term Debt (c)
80
DividendsOnPreferredStock
Dividends on Preferred Stock
81
DividendsOnCommonStock
Dividends on Common Stock
745,361,546
577,998,138
83
CashFlowsProvidedFromUsedInFinancingActivities
Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)
896,436,711
1,407,069,917
85
NetIncreaseDecreaseInCashAndCashEquivalentsAbstract
Net Increase (Decrease) in Cash and Cash Equivalents
86
NetIncreaseDecreaseInCashAndCashEquivalents
Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83)
34,994,337
65,085,626
88
CashAndCashEquivalents
Cash and Cash Equivalents at Beginning of Period
34,638,836
99,724,462
90
CashAndCashEquivalents
Cash and Cash Equivalents at End of Period
69,633,173
34,638,836


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities
Changes in comparative balance sheet for certain accounts
Current and Accrued Assets
$ (34,054,647)
Deferred Debits
(217,977,600)
Amortization of Long-Term Debt Expense
1,581,522 
Counterparty Collateral (Posted) Received, Net
28,250 
Other Noncurrent Liabilities
(20,305,051)
Current and Accrued Liabilities
(157,522,138)
Deferred Credits
216,385,579 
Fleet Depreciation
8,809,624 
Restricted Cash (60,908,057)
Total Operating Activities - Other
$ (263,962,518)
(b) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities
Changes in comparative balance sheet for certain accounts
Utility Plant
$ 38,310,254 
Other Property and Investments
22,010 

$ 38,332,264 
(c) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
The amount represents indemnification from Exelon Corporation, the respondent's parent, to support expanded capital programs.
(d) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities
Changes in comparative balance sheet for certain accounts
Current and Accrued Assets
$ (26,450,590)
Gain on Disposal of Property
1,777,495 
Deferred Debits
(217,821,468)
Amortization of Long-Term Debt Expense
1,446,389 
Counterparty Collateral (Posted) Received, Net
15,286,909 
Other Noncurrent Liabilities
(60,539,727)
Current and Accrued Liabilities
241,366,530 
Deferred Credits
42,867,033 
Fleet Depreciation
8,117,668 
Restricted Cash (155,698,052)
Unamortized Debt Expenses (158,720)
Other
1,027 
Total Operating Activities - Other
$ (149,805,506)
(e) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities
Changes in comparative balance sheet for certain accounts
Utility Plant
$ 26,196,916 
Other Property and Investments
69,998 
Miscellaneous and Accrued Assets
(210,817)

$ 26,056,097
(f) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
The amount represents indemnification from Exelon Corporation, the respondent's parent, to support expanded capital programs.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
NOTES TO FINANCIAL STATEMENTS
  1. Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement.
  2. Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock.
  3. For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Commission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof.
  4. Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts.
  5. Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
  6. If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein.
  7. For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
  8. For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred.
  9. Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.
The notes presented herein were derived from the notes disclosed within the Annual Report of the Exelon Corporation (Exelon) on Form 10-K for the fiscal year ended December 31, 2023. The notes presented herein were modified to include information relevant to Commonwealth Edison Company (ComEd). All amounts presented within the footnotes are rounded in millions unless otherwise noted.
1. Significant Accounting Policies
Description of Business
ComEd was organized in the State of Illinois in 1913 as a result of the merger of Cosmopolitan Electric Company into the original corporation named Commonwealth Edison Company, which was incorporated in 1907. ComEd is engaged principally in the purchase and regulated retail sale of electricity and the provision of distribution and transmission services to a diverse base of residential, commercial, industrial and wholesale customers in Northern Illinois, including the City of Chicago. ComEd’s retail service territory has an area of approximately 11,450 square miles and an estimated population of 9.2 million. The service territory includes the City of Chicago, an area of about 225 square miles with an estimated population of 2.6 million. ComEd has approximately 4.1 million customers.
Basis of Presentation
ComEd is a principal indirect subsidiary of Exelon, which owns more than 99% of ComEd’s common stock.
Accounting policies for regulated operations are in accordance with those prescribed by the regulatory authorities having jurisdiction, principally the Illinois Commerce Commission (ICC) under state public utility laws and the Federal Energy Regulatory Commission (FERC). The accompanying financial statements have been prepared in accordance with the accounting requirements of FERC as set forth in the Uniform System of Accounts (USOA) and accounting releases, which differ from accounting principles generally accepted in the United States (GAAP). The principal differences from GAAP include the exclusions of current maturities of long-term debt from current liabilities, the exclusion of debt issuance costs from long-term debt, the requirement to report deferred tax assets and liabilities separately rather than as a single amount, the classification of accrued taxes as assets and liabilities rather than a net amount, the exclusion of FIN 48 liabilities related to temporary income tax differences, the derecognition of operating leases from the balance sheet, the classification of cloud computing costs, and the classification of certain other assets and liabilities as current instead of noncurrent.
ComEd’s investments in Commonwealth Edison Company of Indiana, Inc. (ComEd of Indiana), RITELine Illinois, LLC and EdiSun, LLC are accounted for under the equity method of accounting in accordance with the USOA. These entities are consolidated in ComEd’s GAAP financial statements.
ComEd’s investment in ComEd Financing III is accounted for under the equity method of accounting in accordance with the USOA. This entity is not consolidated in ComEd’s GAAP financial statements.
COVID-19

ComEd has taken steps to mitigate the potential risks posed by the global outbreak (pandemic) of the 2019 novel coronavirus (COVID-19). ComEd provides a critical service to its customers and has taken measures to keep employees who operate the business safe and minimize unnecessary risk of exposure to the virus, including extra precautions for employees who work in the field. ComEd has implemented work from home policies where appropriate.

Management makes estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and accompanying notes, and the amounts of revenues and expenses reported during the periods covered by those financial statements and accompanying notes. As of December 31, 2023 and 2022, and through the date of the report, management assessed certain accounting matters that require consideration of forecasted financial information, including, but not limited to, our accumulated provision for uncollectible accounts and the carrying value of goodwill and other long-lived assets, in context with the information reasonably available and the unknown future impacts of COVID-19. ComEd's future assessment of the magnitude and duration of COVID-19, as well as other factors, could result in material impacts to the financial statements in future reporting periods.
Use of Estimates
The preparation of financial statements in conformity with USOA requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Areas in which significant estimates
have been made include, but are not limited to, the accounting for pension and other postretirement benefits (OPEB), unbilled energy revenues, allowance for uncollectible accounts, inventory reserves, goodwill, and long-lived asset impairments, derivative instruments, fixed asset depreciation, environmental costs and other loss contingencies, asset retirement obligations (AROs), and taxes. Actual results could differ from those estimates.
Regulatory Accounting
For its regulated electric operations, ComEd reflects the effects of cost-based rate regulation in its financial statements, which is required for entities with regulated operations that meet the following criteria: 1) rates are established or approved by a third-party regulator; (2) rates are designed to recover the entities’ cost of providing services or products; and (3) there is a reasonable expectation that rates designed to recover costs can be charged to and collected from customers. ComEd accounts for their regulated operations in accordance with regulatory and legislative guidance from the regulatory authority having jurisdiction, principally the ICC, under state public utility laws and the FERC under various Federal laws. Regulatory assets and liabilities are amortized and the related expense or revenue is recognized in the Statement of Income consistent with the recovery or refund included in customer rates. ComEd's regulatory assets and liabilities as of the balance sheet date are probable of being recovered or settled in future rates. If a separable portion of ComEd's business was no longer able to meet the criteria discussed above, ComEd would be required to eliminate from its financial statements the effects of regulation for that portion, which could have a material impact on its financial statements. See Note 2—Regulatory Matters for additional information.
ComEd treats the impacts of a final rate order received after the balance sheet date but prior to the issuance of the financial statements as a non-recognized subsequent event, as the receipt of a final rate order is a separate and distinct event that has future impacts on the parties affected by the order.
Revenues
Operating Revenues. ComEd’s operating revenues generally consist of revenues from contracts with customers involving the sale and delivery of power, utility revenues from alternative revenue programs (ARP), and realized and unrealized revenues recognized under mark-to-market energy commodity derivative contracts. ComEd recognizes revenue from contracts with customers to depict the transfer of goods or services to customers in an amount that the entities expect to be entitled to in exchange for those goods or services. ComEd's primary sources of revenue include regulated electric tariff sales, distribution and transmission services. At the end of each month, the ComEd accrues an estimate for the unbilled amount of energy delivered or services provided to customers.
ComEd records ARP revenue for its best estimate of the electric distribution, energy efficiency, distributed generation rebates, and transmission revenue impacts resulting from future changes in rates that ComEd believes are probable of approval by the ICC and FERC in accordance with its formula rate mechanisms. See Note 2—Regulatory Matters for additional information.
Taxes Directly Imposed on Revenue-Producing Transactions. ComEd collects certain taxes from customers such as sales and gross receipts taxes, along with other taxes, surcharges and fees, that are levied by state or local governments on the sale or distribution of electricity. Some of these taxes are imposed on the customer, but paid by ComEd, while others are imposed on ComEd. Where these taxes are imposed on the customer, such as sales taxes, they are reported on a net basis with no impact to the Statement of Income. However, where these taxes are imposed on ComEd, such as gross receipts taxes or other surcharges or fees, they are reported on a gross basis. Accordingly, revenues are recognized for the taxes collected from customers along with an offsetting expense. See Note 14— Supplemental Financial Information for ComEd’s utility taxes that are presented on a gross basis.
Income Taxes
Deferred federal and state income taxes are recorded on significant temporary differences between the book and tax basis of assets and liabilities and for tax benefits carried forward. Investment tax credits have been deferred in ComEd's Balance Sheets and are recognized in book income over the life of the related property. In accordance with USOA, ComEd reports deferred income tax balances arising from temporary differences in Accounts 190, 282 and 283 as appropriate, which differs from the net presentation required by GAAP. See Note 7—Income Taxes for additional information. ComEd recognizes accrued interest related to unrecognized tax benefits in interest expense or interest income in Net Interest Charges and Other Income, respectively on its Statements of Income.
ComEd accounts for uncertain income tax positions using a benefit recognition model with a two-step approach; a more-likely-than-not recognition criterion; and a measurement approach that measures the position as the largest amount of tax benefit that is greater than 50% likely of being realized upon ultimate settlement. If it is not more-likely-than-not that the benefit of the tax position will be sustained on its technical merits, no benefit is recorded. Uncertain tax positions that relate only to timing of when an item is included on a tax return are considered to have met the recognition threshold.
ComEd accounts for uncertain income tax positions in accordance with FERC's guidance on Accounting and Financial Reporting for Uncertainty in Income Taxes, issued in Docket No. AI07-2-000 for FERC reporting purposes. The guidance requires, among other things, that entities should continue to recognize deferred income taxes for FERC accounting and reporting purposes based on the difference between positions taken in tax returns filed or expected to be filed and amounts reported in financial statements.
Cash and Cash Equivalents
ComEd considers investments purchased with an original maturity of three months or less to be cash equivalents.
Restricted Cash and Cash Equivalents
Restricted cash and cash equivalents represent funds that are restricted to satisfy designated current liabilities. As of December 31, 2023 and 2022, ComEd’s restricted cash and cash equivalents primarily represented cash collateral held from suppliers associated with ComEd’s energy and renewable energy credits (REC) procurement contracts, any over-recovered Renewable Energy Portfolio Standards (RPS) costs and alternative compliance payments received from Retail Electric Suppliers (RES) pursuant to the Future Energy Jobs Act (FEJA), and costs for the remediation of a Manufactured Gas Plant (MGP) site.
Restricted cash and cash equivalents not available to satisfy current liabilities are classified as noncurrent assets. As of December 31, 2020 and 2019, ComEd's noncurrent restricted cash and cash equivalents primarily represented over-recovered RPS costs and alternative compliance payments received from RES pursuant to FEJA and costs for the remediation of an MGP site.
Accumulated Provision for Uncollectible Accounts on Accounts Receivables
The accumulated provision for uncollectible accounts reflects ComEd's best estimate of losses on the customers' accounts receivable balances based on historical experience, current information, and reasonable and supportable forecasts.
The accumulated provision for uncollectible accounts for ComEd's customers is developed by applying ComEd's loss rates, based on historical loss experience, current conditions, and forward looking risk factors, to the outstanding receivable balance by customer risk segment. ComEd's customer accounts are written off consistent with approved regulatory requirements. Adjustments to the accumulated provision for uncollectible accounts are primarily recorded to Operating and maintenance expense on ComEd's Statement of Income or Regulatory assets and liabilities on ComEd's Balance Sheet. See Note 2 — Regulatory Matters for additional information regarding the regulatory recovery of uncollectible accounts expense on customers' accounts receivable.
ComEd has certain non-customer receivables in Other deferred debits and other assets which primarily are with governmental agencies and other high-quality counterparties with no history of default. As such, the accumulated provision for uncollectible accounts related to these receivables is not material. ComEd monitors these balances and will record an allowance if there are indicators of a decline in credit quality. See Note 3 — Accounts Receivable for additional information.
Inventories
Inventory is recorded at the lower of weighted average cost or net realizable value. Provisions are recorded for excess and obsolete inventory. Materials and supplies are generally included in inventory when purchased. Materials and supplies inventory generally includes transmission and distribution materials and are expensed to Operating and maintenance or capitalized to Property, plant, and equipment, as appropriate, when installed or used.
Property, Plant and Equipment
Property, plant and equipment is recorded at original cost. Original cost includes construction-related direct labor and material costs and indirect construction costs including labor and related costs of departments associated with supporting construction activities. When appropriate, original cost also includes allowance for funds used during construction (AFUDC) for regulated property. The cost of repairs and maintenance and minor replacements of property is charged to Operating and maintenance expense as incurred.
Third parties reimburse ComEd for all or a portion of expenditures for certain capital projects. Such contributions in aid of construction costs (CIAC) are recorded as a reduction to Property, plant and equipment, net.
Upon retirement, the cost of property, net of salvage, is charged to accumulated depreciation consistent with the composite and group methods of depreciation. Depreciation expense includes the estimated cost of dismantling and removing plant from service upon retirement. Actual incurred removal costs are applied against a related regulatory liability or recorded to a regulatory asset if in excess of previously collected removal costs.
Capitalized Software. Certain costs, such as design, coding, and testing incurred during the application development stage of software projects that are internally developed or purchased for operational use are capitalized within Property, plant, and equipment. Similar costs incurred for cloud-based solutions treated as service arrangements are capitalized within Property, plant, and equipment. Such capitalized amounts are amortized ratably over the expected lives of the projects when they become operational, generally not to exceed five years. Certain other capitalized software costs are being amortized over longer lives, based on the expected life or pursuant to prescribed regulatory requirements.
Allowance for Funds Used During Construction (AFUDC). AFUDC is the cost, during the period of construction, of debt and equity funds used to finance construction projects for regulated operations. AFUDC is recorded to construction work in progress and as a non-cash credit to an allowance that is included in interest expense for debt-related funds and other income and deductions for equity-related funds. The rates used for capitalizing AFUDC are computed under a method prescribed by regulatory authorities.
See Note 4 — Property, Plant, and Equipment for additional information.
Depreciation and Amortization
Depreciation is generally recorded over the estimated service lives of property, plant and equipment on a straight-line basis using the group, composite, or unitary methods of depreciation. The group approach is typically for groups of similar assets that have approximately the same useful lives and the composite approach is used for dissimilar assets that have different lives. Under both methods, a reporting entity depreciates the assets over the average life of the assets in the group. ComEd's depreciation expense includes the estimated cost of dismantling and removing plant from service upon retirement, which is consistent with ComEd's regulatory recovery method. The estimated service lives for ComEd are based on a combination of depreciation studies, historical retirements, site licenses, and management estimates of operating costs and expected future energy market conditions. See Note 4Property, Plant, and Equipment for additional information regarding depreciation.
Amortization of regulatory assets and liabilities is recorded over the recovery or refund period specified in the related legislation or regulatory order or agreement. When the recovery or refund period is less than one year, amortization is recorded to the line item in which the deferred cost or income would have originally been recorded in ComEd's Statement of Income. Amortization of ComEd’s electric distribution and energy efficiency formula rate regulatory assets and ComEd’s transmission formula rate regulatory asset is recorded to Operating revenues.
Amortization of income tax related regulatory assets and liabilities is generally recorded to Income tax expense. Except for the regulatory assets and liabilities discussed above, amortization is generally recorded to Depreciation and amortization in ComEd's Statement of Income when the recovery period is more than one year.
See Note 2Regulatory Matters for additional information regarding the amortization of ComEd’s regulatory assets and liabilities.
Asset Retirement Obligations
ComEd updates its AROs either annually or on a rotational basis at least once every three years, based on a risk profile, unless circumstances warrant more frequent updates. The updates factor in new cost estimates, credit-adjusted, risk-free rates (CARFR) and escalation rates, and the timing of cash flows. AROs are accreted throughout each year to reflect the time value of money for these present value obligations through an increase to regulatory assets. See Note 5 — Asset Retirement Obligations for additional information.
Guarantees
If necessary, ComEd recognizes a liability at the time of issuance of a guarantee for the fair value of the obligations it has undertaken by issuing the guarantee.
The liability is reduced or eliminated as ComEd is released from risk under the guarantee. Depending on the nature of the guarantee, ComEd's release from risk may be recognized only upon the expiration or settlement of the guarantee or by a systematic and rational amortization method over the term of the guarantee. See Note 12—Commitments and Contingencies for additional information.
Asset Impairments
Long-Lived Assets. ComEd evaluates the carrying value of its long-lived assets for recoverability whenever events or changes in circumstances indicate that the carrying value of those assets may not be recoverable. Indicators of impairment may include specific regulatory disallowance, abandonment, or plans to dispose of a long-lived asset significantly before the end of its useful life. When the estimated undiscounted future cash flows attributable to the long-lived asset may not be
recoverable, the amount of the impairment loss is determined by measuring the excess of the carrying amount of the long-lived asset over its fair value.
Goodwill. Goodwill represents the excess of the purchase price paid over the estimated fair value of the net assets acquired and liabilities assumed in the acquisition of a business. Goodwill is not amortized but is assessed for impairment at least annually or on an interim basis if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. See Note 6 - Intangible Assets for additional information.
Derivative Financial Instruments
All derivatives are recognized on the balance sheet at their fair value unless they qualify for certain exceptions, including the normal purchases and normal sales (NPNS) exception. For derivatives intended to serve as economic hedges, changes in fair value are recognized in earnings each period. Amounts classified in earnings are included in Operating revenue, Purchased power, Interest expense, or Other, net in the Statement of Income based on the activity the transaction is economically hedging. While the majority of the derivatives serve as economic hedges, there are also derivatives entered into for proprietary trading purposes, subject to ComEd's Risk Management Policy, and changes in the fair value of those derivatives are recorded in revenue in the Statement of Income. At ComEd, changes in fair value may be recorded as a regulatory asset or liability if there is an ability to recover or return the associated costs. Cash inflows and outflows related to derivative instruments are included as a component of operating, investing or financing cash flows in the Statement of Cash Flows, depending on the nature of each transaction.
NPNS are contracts where physical delivery is probable, quantities are expected to be used or sold in the normal course of business over a reasonable period and will not be financially settled. Revenues and expenses on derivative contracts that qualify, and are designated, as NPNS are recognized when the underlying physical transaction is completed. While these contracts are considered derivative financial instruments, they are not required to be recorded at fair value. See Note 9 - Derivative Financial Instruments for additional information.
Retirement Benefits
ComEd participates in Exelon’s defined benefit pension plans and OPEB plans.
The plan obligations and costs of providing benefits under these plans are measured as of December 31. The measurement involves various factors, assumptions and accounting elections. The impact of assumption changes or experience different from that assumed on pension and OPEB obligations is recognized over time rather than immediately recognized in the Statement of Income. Gains or losses in excess of the greater of ten percent of the projected benefit obligation or the market-related value of plan assets are amortized over the expected average remaining service period of plan participants. See Note 8— Retirement Benefits for additional information.
New Accounting Pronouncements
New Accounting Standards Issued and Not Yet Adopted as of December 31, 2023
The following new authoritative accounting guidance issued by the FASB has not yet been adopted and reflected by ComEd in their financial statements as of December 31, 2023. Unless otherwise indicated, ComEd is currently assessing the impacts such guidance may have (which could be material) in their Balance Sheet, Statement of Income, Statement of Cash Flows and disclosures, as well as the potential to early adopt where applicable. ComEd has assessed other FASB issuances of new standards which are not listed below given the current expectation that such standards will not significantly impact ComEd's financial reporting.
Improvement to Income Tax Disclosures (Issued December 2023). Provides additional disclosure requirements related to the effective tax rate reconciliation and income taxes paid. Under the revised guidance for the effective tax reconciliations, entities would be required to disclose: (1) eight specific categories in the effective tax rate reconciliation in both percentages and reporting currency amount, (2) additional information for reconciling items over a certain threshold, (3) explanation of individual reconciling items disclosed, and (4) provide a qualitative description of the state and local jurisdictions that contribute to the majority of the state income tax expense. For each annual period presented, the new standard requires disclosure of the year-to-date amount of income taxes paid (net of refunds received) disaggregated by federal, state, and foreign. It also requires additional disaggregated information on income taxes paid (net of refunds received) to an individual jurisdiction equal to or greater than 5% of total income taxes paid (net of refunds received). The standard is effective January 1, 2025, with early adoption permitted.
2. Regulatory Matters
The following matters below discuss the status of material regulatory and legislative proceedings of ComEd.
Distribution Base Rate Case Proceedings
The following tables show the completed and pending distribution base rate case proceedings in 2023.
Completed Distribution Base Rate Case Proceedings
JurisdictionFiling DateServiceRequested Revenue Requirement IncreaseApproved Revenue Requirement IncreaseApproved ROEApproval DateRate Effective Date
Illinois
April 15, 2022(a)
Electric$199 $199 7.85 %November 17, 2022January 1, 2023
January 17, 2023(b)
$1,487 $501 8.905 %December 14, 2023January 1, 2024
April 21, 2023(c)
$247 $259 8.91 %November 30, 2023January 1, 2024
__________
(a) ComEd’s 2023 approved revenue requirement above reflects an increase of $144 million for the initial year revenue requirement for 2023 and an increase of $55 million related to the annual reconciliation for 2021. The revenue requirement for 2023 provides for a weighted average debt and equity return on distribution rate base of 5.94% inclusive of an allowed ROE of 7.85%, reflecting the monthly average yields for 30-year treasury bonds plus 580 basis points. The reconciliation revenue requirement for 2021 provides for a weighted average debt and equity return on distribution rate base of 5.91%, inclusive of an allowed ROE of 7.78%, reflecting the monthly yields on 30-year treasury bonds plus 580 basis points less a performance metrics penalty of 7 basis points. ComEd's last performance-based electric distribution formula rate update filing under EIMA was completed in 2022. See discussion of CEJA below for details on the transition away from the electric distribution formula rate.
(b) Reflects a four-year cumulative multi-year rate plan for January 1, 2024 to December 31, 2027. On December 14, 2023, the ICC approved year-over-year distribution revenue requirement increases in 2024-2027, with an amendatory order on January 10, 2024, of approximately $451 million effective January 1, 2024, $14 million effective January 1, 2025, $6 million effective January 1, 2026, and $30 million effective January 1, 2027, based on an ROE of 8.905%, an equity ratio of 50%, and year end 2022 rate base. The ICC rejected ComEd’s Grid Plan, requiring ComEd to file a revised Grid Plan by March 13, 2024, 90 days after the issuance of the December final order. The ICC also directed that the revised Grid Plan would be reviewed through further formal proceedings in that docket. On January 10, 2024, the ICC granted one portion of ComEd’s application for rehearing of the December 14, 2023 final order, and directing that a 150-day rehearing process reconsider the revenue requirements for the test years (2024-2027), absent an approved Grid Plan. On January 31,2024, the ICC further clarified the scope of the rehearing process. ComEd anticipates that the revenue requirements determined during the rehearing process will be further updated upon approval of a revised Grid Plan. On January 10, 2024, ComEd also filed with the Illinois appellate court an appeal of various aspects of the ICC’s final order on which rehearing was denied, including the 8.905% ROE, 50% equity ratio, and denial of any return on ComEd’s pension asset. On March 13, 2024, ComEd filed its revised Grid Plan with supporting testimony and schedules with the ICC. On March 15, 2024, ComEd filed a petition to adjust its MRP to authorize increased rates consistent with the March 13 refiled Grid Plan.
(c) On November 30, 2023, the Delivery Reconciliation Amount for 2022 defined in Rider Delivery Service Pricing Reconciliation (Rider DSPR) was approved. The delivery reconciliation amount allows for the reconciliation of the revenue requirement in effect in the final years in which formula rates are determined and until such time as new rates are established under ComEd’s approved MRP. The 2023 filing reconciled the delivery service rates in effect in 2022 with the actual delivery service costs incurred in 2022. The reconciliation revenue requirement provides for a weighted average debt and equity return on distribution rate base of 6.48%, inclusive of an allowed ROE of 8.91%, reflecting the monthly yields on 30-year treasury bonds plus 580 basis points.
Transmission Formula Rates
ComEd’s transmission rate is established based on a FERC-approved formula. ComEd is required to file an annual update to the FERC-approved formula on or before May 15, with the resulting rate effective on June 1 of the same year. The annual update is based on prior year actual costs and current year projected capital additions (initial year revenue requirement). The update also reconciles any differences between the revenue requirement in effect beginning June 1 of the prior year and actual costs incurred for that year (annual reconciliation).
For 2023, the following total increases/(decreases) was included in ComEd’s electric transmission formula rate update:
Filing Date(a)
Initial Revenue Requirement Increase
Annual Reconciliation Decrease
Total Revenue Requirement Increase
Allowed Return on Rate Base(b)
Allowed ROE(c)
May 12, 2023$20 $63 $83 8.09 %11.50 %
__________
(a)All rates are effective June 1, 2023 - May 31, 2024, subject to review by interested parties pursuant to review protocols of ComEd's tariff.
(b)Represents the weighted average debt and equity return on transmission rate bases. The common equity component of the ratio used to calculate the weighted average debt and equity return on the transmission formula rate base is currently capped at 55%.
(c)The rate of return on common equity includes a 50-basis-point incentive adder for being a member of a RTO.
Other State Regulatory Matters
Illinois Regulatory Matters
Clean and Equitable Jobs Act (CEJA). On September 15, 2021, the Governor of Illinois signed into law CEJA. CEJA includes, among other features, (1) procurement of CMCs from qualifying nuclear-powered generating facilities, (2) a requirement to file a general rate case or a new four-year MRP no later than January 20, 2023 to establish rates effective after ComEd’s existing performance-based distribution formula rate sunsets, (3) requirements that ComEd and the ICC initiate and conduct various regulatory proceedings on subjects including ethics, spending, grid investments, and performance metrics.
ComEd Electric Distribution Rates

ComEd filed, and received approval for, its last performance-based electric distribution formula rate update under EIMA in 2022; those rates were in effect throughout 2023.

On February 3, 2022, the ICC approved a tariff that establishes the process under which ComEd reconciled its 2022 and will reconcile its 2023 rate year revenue requirements with actual costs. Those reconciliation amounts are determined using the same process used for prior reconciliations under the performance-based electric distribution formula rate. Using that process, for the rate years 2022 and 2023 ComEd will ultimately collect revenues from customers reflecting each year’s actual recoverable costs, year-end rate base, and a weighted average debt and equity return on distribution rate base, with the ROE component based on the annual average of the monthly yields of the 30-year U.S. Treasury bonds plus 580 basis points. In April 2023, ComEd filed its first petition with the ICC to reconcile its 2022 actual costs with the approved revenue requirement that was in effect in 2022; the final order was issued on November 30, 2023, for rates beginning January 2024. In 2024, ComEd will file with the ICC its 2023 actual costs with the approved revenue requirement that was in effect in 2023.

Beginning in 2024, ComEd will recover from retail customers, subject to certain exceptions, the costs it incurs to provide electric delivery services either through its electric distribution rate or other recovery mechanisms authorized by CEJA. On January 17, 2023, ComEd filed a petition with the ICC seeking approval of a MRP for 2024-2027. The MRP supports a multi-year grid plan (Grid Plan), also filed on January 17, covering planned investments on the electric distribution system within ComEd’s service area through 2027. Costs incurred during each year of the MRP are subject to ICC review and the plan’s revenue requirement for each year will be reconciled with the actual costs that the ICC determines are prudently and reasonably incurred for that year. The reconciliation is subject to adjustment for certain costs, including a limitation on recovery of costs that are more than 105% of certain costs in the previously approved MRP revenue requirement, absent a modification of the rate plan itself. Thus, for example, the rate adjustments necessary to reconcile 2024 revenues to ComEd’s actual 2024 costs incurred would take effect in January 2026 after the ICC’s review during 2025. On May 22, 2023, direct testimony was filed by ICC staff and more than a dozen intervenors and intervenor groups. The testimonies addressed a wide variety of topics, including rate of return on equity, capital structure, grid planning, various distribution grid and information technology investments, and affordability and customer service. ComEd also made voluntary adjustments and, per the ICC’s final beneficial electrification order requiring ComEd to recover beneficial electrification costs through the MRP, increased its total revenue requirement request from $1.472 billion to $1.545 billion. ComEd filed its reply brief on September 27, 2023, to adjust its total requested revenue requirement increase to $1.487 billion.

On December 14, 2023, the ICC issued a final order. The ICC rejected ComEd’s Grid Plan as non-compliant with certain requirements of CEJA, and required ComEd to file a revised Grid Plan by March 13, 2024, 90 days after the issuance of the final order. In the absence of an approved Grid Plan, the ICC set ComEd’s forecast revenue requirements for 2024-2027 based on ComEd's approved year-end 2022 rate base. This results in a total cumulative revenue requirement increase of $501 million, a $986 million total revenue reduction from the requested cumulative revenue requirement increase but remains subject to annual reconciliation in accordance with CEJA. The final order approved the process and formulas associated with the MRP reconciliation mechanisms. The ICC did not approve a previously proposed phase-in of the ICC's approved year-over-year revenue increases, and it also denied ComEd's ability to earn a return on its pension asset.

On December 22, 2023, ComEd filed an application for rehearing on several findings in the final order including the use of the 2022 year-end rate base to establish forecast revenue requirements for 2024-2027, ROE, pension asset return, and capital structure. On January 10, 2024, ComEd’s application for rehearing was denied on all issues except for the order’s use of the 2022 year-end rate base. On January 31, 2024, the ICC granted ComEd's motion seeking additional clarification on the scope on rehearing, generally accepting ComEd's proposal and confirming that the rehearing will determine if the forecasted year-end 2023 rate base should be used to set rates for 2024 through 2027 until a refiled Grid Plan is approved. A final rehearing order on that topic is statutorily required by early June 2024. On January 10, 2024, ComEd also filed an appeal in the Illinois Appellate Court of the issues on which rehearing was denied, including but not limited to the allowed ROE and denial of a return on ComEd’s pension asset. There is no deadline by when the appellate court must rule. On March 7, 2024, the ICC
adopted an interim order on scheduling, which confirmed that it intends to issue a final order on ComEd’s refiled Grid Plan by the end of 2024 and that it will implement rates that will go into effect January 1, 2025, inclusive of a Grid Plan. On March 13, 2024, ComEd filed its revised Grid Plan with supporting testimony and schedules with the ICC. The Grid Plan is designed to meet or exceed every requirement identified by the ICC in its December order that rejected ComEd’s initial Grid Plan. On March 15, 2024, ComEd filed a petition to adjust its MRP to authorize increased rates consistent with the March 13 refiled Grid Plan. ComEd has completed and placed in service additional utility plant assets in 2023 and 2024 and will continue to complete and place in service additional utility plant assets prior to the approval of the new Grid Plan. There are still significant unknowns, but ComEd does not currently believe that it is probable that the initially uncollected depreciation or return on the recently completed plant will ultimately be disallowed.

In January 2022, ComEd filed a request with the ICC proposing performance metrics that would be used in determining ROE incentives and penalties in the event ComEd filed a MRP in January 2023. On September 27, 2022, the ICC issued a final order approving seven performance metrics that provide symmetrical performance adjustments of 32 total basis points to ComEd’s rate of return on common equity based on the extent to which ComEd achieves the annual performance goals. On November 10, 2022, the ICC granted ComEd's application for rehearing, in part. On April 5, 2023, the ICC issued its final order on rehearing for the performance and tracking metrics proceeding, in which the ICC declined to adopt ComEd's proposed modifications to the reliability and peak load reduction performance metrics. Efforts are underway to implement the performance metrics, which took effect on January 1, 2024. ComEd will make its initial filing in 2025 to assess performance achieved under the metrics in 2024, and to determine any ROE adjustment, which would take effect in 2026.

Carbon Mitigation Credit

CEJA establishes decarbonization requirements for Illinois as well as programs to support the retention and development of emissions-free sources of electricity. ComEd is required to purchase CMCs from participating nuclear-powered generating facilities between June 1, 2022 and May 31, 2027. The price to be paid for each CMC was established through a competitive bidding process that included consumer-protection measures that capped the maximum acceptable bid amount and a formula that reduces CMC prices by an energy price index, the base residual auction capacity price in the ComEd zone of PJM, and the monetized value of any federal tax credit or other subsidy if applicable. The consumer protection measures contained in CEJA will result in net payments to ComEd ratepayers if the energy index, the capacity price and applicable federal tax credits or subsidy exceed the CMC contract price. In the June 2022 billing period. ComEd began issuing credits to its retail customers under its new CMC rider. A regulatory asset is recorded for the difference between customer credits issued and the credit to be received from the participating nuclear-powered generating facilities. The balance as of December 31, 2023 is $673 million.

Under CEJA, the costs of procuring CMCs, including carrying costs, are recovered through a rider, the Rider Carbon-Free Resource Adjustment (Rider CFRA). As originally approved by the ICC, Rider CFRA provides for an annual reconciliation and true-up to actual costs incurred or credits received by ComEd to purchase CMCs, with any difference to be credited to or collected from ComEd’s retail customers in subsequent periods. The difference between the net payments to (or receivables from) ComEd ratepayers and the credits received by ComEd to purchase CMCs is recorded to Purchased power expense with an offset to the regulatory asset (or regulatory liability). On December 21, 2022, ComEd filed an amendment to Rider CFRA proposing that it recover costs or provide credits faster than the tariff allows, implement monthly reconciliations, and allow ComEd to adjust Rider CFRA rates based not only on anticipated differences but also past payments or credits, and implement monthly reconciliations beginning with the June 2023 delivery period. The ICC approved the proposal on January 19, 2023. In addition, on March 24, 2023, ComEd submitted revisions to Rider CFRA which clarified the methodology for calculating interest to be included in the annual reconciliation associated with the June 2022 through May 2023 delivery year. The ICC approved the proposal on April 20, 2023. On February 2, 2024, ComEd filed a petition with the ICC to initiate the reconciliation proceeding for the costs incurred in connection with the procurement of CMCs during the delivery year beginning June 1, 2022 and extending through May 31, 2023.

Excess Deferred Income Taxes

The ICC initiated a docket to accelerate and fully credit to customers TCJA unprotected property-related EDIT no later than December 31, 2025. On July 7, 2022, the ICC issued a final order on the schedule for the acceleration of EDIT amortization, adopting the proposal as submitted by several parties, including ComEd, ICC Staff, the Illinois Attorney General's Office, and the Citizens Utility Board. EDIT amortization will be credited to customers through a new rider from January 1, 2023 through December 31, 2025.

Beneficial Electrification Plan

On March 23, 2023, the ICC issued its final order approving the beneficial electrification plan for ComEd. The ICC rejected ComEd's request to treat a large portion of beneficial electrification costs as a regulatory asset and ordered ComEd to seek cost recovery through the multi-year rate plan filing for 2024 and 2025, and the final formula rate reconciliation docket for
2023, rather than through a separate charge. The order also authorized an overall annual budget of $77 million per year for the three-year plan period (2023 through 2025), with flexibility to roll forward unused funds to future years within the same plan period. On April 18, 2023, ComEd filed an application for rehearing in the beneficial electrification plan docket. The Chicago Transit Authority and City of Chicago, jointly, and the Office of the Illinois Attorney General (ILAG) also filed applications for rehearing. On April 27, 2023, ICC staff filed a motion for clarification, seeking clarification from the ICC on the precise budget described in the final order. On May 8, 2023, the ICC denied all applications for rehearing, and entered an amendatory order regarding the annual beneficial electrification plan budgets. ComEd has been directed to use good faith efforts to spend $77 million annually. ComEd subsequently filed its compliance filing in May 2023, detailing project related spending, clarifying the procedure that will be used to seek stakeholder feedback related to beneficial electrification pilot programs, and including the timeline for tariff changes required to implement the programs. ComEd and the ILAG both filed appeals of the ICC’s interim order that addressed the permissible scope of utility beneficial electrification programs outside of transportation and the rate impact cap. The ILAG also filed an appeal seeking reversal of portions of the ICC’s final decision. The final order partly mooted ComEd’s appeal of the interim order and ComEd has decided not to pursue the other issues. As such, ComEd moved to voluntarily dismiss its appeal and the appellate court granted that request. The ILAG consolidated their appeals. Any ruling on the appeals, even a negative ruling removing programs from the BE Plan or lowering the overall budget of the BE Plan, will only impact forward-looking costs.

Energy Efficiency

CEJA extends ComEd’s current cumulative annual energy efficiency MWh savings goals through 2040, adds expanded electrification measures to those goals, increases low-income commitments and adds a new performance adjustment to the energy efficiency formula rate. ComEd expects its annual spend to increase in 2023 through 2040 to achieve these energy efficiency MWh savings goals, which will be deferred as a separate regulatory asset that will be recovered through the energy efficiency formula rate over the weighted average useful life, as approved by the ICC, of the related energy efficiency measures.

Energy Efficiency Formula Rate. FEJA allows ComEd to defer energy efficiency costs (except for any voltage optimization costs which are recovered through the electric distribution formula rate) as a separate regulatory asset that is recovered through the energy efficiency formula rate over the weighted average useful life, as approved by the ICC, of the related energy efficiency measures. ComEd earns a return on the energy efficiency regulatory asset at a rate equal to its weighted average cost of capital, which is based on a year-end capital structure and calculated using the same methodology applicable to ComEd’s electric distribution formula rate. Beginning January 1, 2018, the ROE that ComEd earns on its energy efficiency regulatory asset is subject to a maximum downward or upward adjustment of 200 basis points if ComEd’s cumulative persisting annual MWh savings falls short of or exceeds specified percentage benchmarks of its annual incremental savings goal. ComEd is required to file an update to its energy efficiency formula rate on or before June 1st each year, with resulting rates effective in January of the following year. The annual update is based on projected current year energy efficiency costs, PJM capacity revenues, and the projected year-end regulatory asset balance less any related deferred income taxes (initial year revenue requirement). The update also reconciles any differences between the revenue requirement in effect for the prior year and actual costs incurred from the year (annual reconciliation). The approved energy efficiency formula rate also provides for revenue decoupling provisions similar to those in ComEd’s electric distribution formula rate.
During 2023, the ICC approved the following total increases in ComEd's requested energy efficiency revenue requirement:
Filing DateRequested Revenue Requirement Increase
Approved Revenue Requirement Increase(a)
Approved ROEApproval DateRate Effective Date
May 26, 2023$118 $118 8.91 %November 30, 2023January 1, 2024
_________
(a)ComEd's 2024 approved revenue requirement above reflects an increase of $71 million for the initial year revenue requirement for 2024 and a increase of $47 million related to the annual reconciliation for 2022. The revenue requirement for 2024 provides for a weighted average debt and equity return on the energy efficiency regulatory asset and rate base of 6.48% inclusive of an allowed ROE of 8.91%, reflecting the monthly average yields for 30-year treasury bonds plus 580 basis points. The revenue requirement for the 2022 reconciliation year provides for a weighted average debt and equity return on the energy efficiency regulatory asset and rate base of 7.47% inclusive of an allowed ROE of 10.89%, which includes an upward performance adjustment that increased the ROE. The performance adjustment can either increase or decrease the ROE based upon the achievement of energy efficiency savings goals. See table below for ComEd's regulatory assets associated with its energy efficiency formula rate.
Other Federal Regulatory Matters
FERC Audit. ComEd is subject to periodic audits and investigations by FERC. FERC’s Division of Audits and Accounting initiated a nonpublic audit of ComEd in April 2021 evaluating ComEd’s compliance with (1) approved terms, rates and conditions of its federally regulated service; (2) accounting requirements of the Uniform System of Accounts; (3) reporting requirements of the FERC Form 1; and (4) the requirements for record retention. The audit period extends back to January 1,
2017. During the first quarter of 2023, ComEd was provided with information from FERC about several potential findings, including ComEd's methodology regarding the allocation of certain overhead costs to capital under FERC regulations. Based on the preliminary findings and discussions with FERC staff, ComEd determined that a loss was probable and recorded a regulatory liability to reflect its best estimate of that loss in the first quarter of 2023.
On July 27, 2023, FERC issued a final audit report which included, among other things, findings and recommendations related to ComEd's methodology regarding the allocation of certain overhead costs to capitalized construction costs under FERC regulations, including a suggestion that refunds may be due to customers for amounts collected in previous years. On August 28, 2023, ComEd filed a formal notice of the issues it will contest. On December 14, 2023, FERC appointed a settlement judge for the contested overhead allocation findings and set the matter for a trial-type hearing. That hearing process has been held in abeyance while a formal settlement process, which began in February 2024, takes place. The final outcome and resolution of any contested audit issues as well as a reasonable estimate of potential future losses cannot be accurately estimated at this stage; however, the final resolution of these matters could result in recognition of future losses, above the amounts currently accrued, that could be material to the Exelon and ComEd financial statements.
Regulatory Assets and Liabilities
Regulatory assets represent incurred costs that have been deferred because of their probable future recovery from customers through regulated rates. Regulatory liabilities represent the excess recovery of costs or accrued credits that have been deferred because it is probable such amounts will be returned to customers through future regulated rates or represent billings in advance of expenditures for approved regulatory programs.
The following tables provide information about the regulatory assets and liabilities of ComEd as of December 31, 2023 and 2022.
Regulatory Assets (Account 182.3):December 31, 2023December 31, 2022
AMI programs - legacy meters$28 $48 
Asset retirement obligations104 99 
Carbon mitigation credit673 843 
COVID-1911 20 
Deferred income taxes284 — 
Electric distribution formula rate annual reconciliations787 271 
Electric distribution formula rate significant one-time events89 115 
Energy efficiency costs1,691 1,434 
MGP remediation costs286 293 
Renewable energy134 85 
Uncollectible accounts expense78 47 
Zero emissions program58 — 
Other174 169 
Total Regulatory Assets$4,397 $3,424 
Regulatory Liabilities (Account 254):December 31, 2023December 31, 2022
Decommissioning the Regulatory Agreement Units$2,954 $2,660 
Deferred income taxes2,178 2,005 
Electric energy costs13 
Renewable portfolio standards costs1,102 810 
Transmission formula rate annual reconciliations14 
Other
Total Regulatory Liabilities$6,254 $5,499 
Descriptions of the regulatory assets and liabilities included in the tables above are summarized below, including their recovery and amortization periods.
Line ItemDescriptionEnd Date of Remaining Recovery/Refund PeriodReturn
AMI programs - Legacy MetersRepresents early retirement costs of legacy meters.2028Yes
Line ItemDescriptionEnd Date of Remaining Recovery/Refund PeriodReturn
Asset retirement obligationsRepresents future legally required removal costs associated with existing AROs.Over the life of the related assets.Yes, once the removal activities have been performed.
Carbon mitigation creditRepresents CMC procurement costs and credits as well as reasonable costs ComEd has incurred to implement and comply with the CMC procurement process.2024No
COVID-19Represents incremental credit losses and direct costs related to COVID-19 incurred primarily in 2020. Direct costs consistent primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.2025Yes
Decommissioning the Regulatory Agreement Units
Represents estimated excess funds at the end of decommissioning the Regulatory Agreement Units. See below regarding Decommissioning the Regulatory Agreement Units for additional information.
Not currently being refunded.No
Dedicated facilities chargeRepresents the timing difference between the recovery of certain transmission-related assets and their depreciable life.Depreciable life of the related assets.Yes
Line ItemDescriptionEnd Date of Remaining Recovery/Refund PeriodReturn
Deferred income taxesRepresents deferred income taxes that are recoverable or refundable through customer rates, primarily associated with accelerated depreciation, the equity component of AFUDC, and the effects of income tax rate changes, including those resulting from the TCJA.Amounts are recoverable over the period in which the related deferred income taxes reverse, which is generally based on the expected life of the underlying assets. For TCJA, generally refunded over the remaining depreciable life of the underlying assets, except in certain jurisdictions where the commissions have approved a shorter refund period for certain assets not subject to IRS normalization rules.No
Electric distribution formula rate annual reconciliations
Represents under/(over)-recoveries related to electric distribution service costs recoverable through ComEd's performance-based formula rate, which is updated annually with rates effective on January 1st.2025Yes
Electric distribution formula rate significant one-time events
Represents deferred distribution service costs related to ComEd's significant one-time events (e.g., storm costs), which are recovered over 5 years from date of the event.2027Yes
Electric energy costsUnder (over) recoveries related to energy related costs recoverable (refundable) under approved rate riders.2025No
Energy efficiency costs
Represents ComEd's costs recovered through the energy efficiency formula rate tariff and the reconciliation of the difference of the revenue requirement in effect for the prior year and the revenue requirement based on actual prior year costs. Deferred energy efficiency costs are recovered over the weighted average useful life of the related energy measure.2035Yes
MGP remediation costs
Represents environmental remediation costs for MGP sites.
Over the expected remediation period. See Note 12 - Commitments and Contingencies for additional information.
No
Removal costsRepresents amounts received from customers through depreciation rates to cover the future non–legally required cost to remove property, plant and equipment, which reduces rate base for ratemaking purposes.Liability is reduced as costs are incurred.Yes
Renewable energyRepresents the change in fair value of ComEd‘s 20-year floating-to-fixed long-term renewable energy swap contracts. 2032
No
Line ItemDescriptionEnd Date of Remaining Recovery/Refund PeriodReturn
Renewable portfolio standard costsRepresents an overcollection of funds from both ComEd customers and alternative retail electricity suppliers to be spent on future renewable energy commitments.$1,033 million to be determined in pending ICC annual reconciliation for the Renewable Energy Adjustment rider.

$69 million to be determined based on the Long-Term Renewable Resources Procurement Plan developed by the Illinois Power Agency
No
Transmission formula rate annual reconciliations
Under (over)-recoveries related to transmission service costs recoverable through ComEd’s FERC formula rates, which are updated annually with rates effective each June 1st.
2025Yes
Under-recovered uncollectible accounts expenseAmounts represent the difference between annual uncollectible accounts loss expense and revenues collected in rates through ICC-approved riders. The difference between uncollectible accounts expense and revenues collected through rider each calendar year is recovered over a twelve-month period beginning in June of the following calendar year. 2024No
Zero emission creditRepresents ZEC procurement costs and any reasonable costs ComEd has incurred to implement and comply with the ZEC procurement process.Over 9 months starting with the September billing period and ending with the following May billing period.No
Decommissioning the Regulatory Agreement Units
The regulatory agreements with the ICC dictates obligations related to the shortfall or excess of Nuclear Decommissioning Trust (NDT) funds necessary for decommissioning the former ComEd units on a unit-by-unit basis. Given no further recovery from customers is permitted and Constellation retains an obligation to ultimately return excess funds to ComEd customers (on a unit-by-unit basis), to the extent excess funds are expected for each unit, decommissioning-related activities prior to separation on February 1, 2022 were offset in the Statement of Income with an offsetting adjustment to regulatory liabilities and noncurrent receivable from Generation (which is reported within Miscellaneous deferred debits on the Balance Sheet). Following the separation, decommissioning-related activities result in an adjustment to other deferred debits and an equal adjustment to the regulatory liabilities at ComEd. However, given the asymmetric settlement provision that does not allow for continued recovery from ComEd customers in the event of a shortfall, recognition of a regulatory asset is not permissible.
Capitalized Ratemaking Amounts Not Recognized
As of December 31, 2023 and 2022, ComEd had $32 million and $8 million, respectively, of authorized amounts capitalized for ratemaking purposes related to earnings on shareholders' investment on its electric distribution formula rate regulatory assets that are not recognized for financial reporting purposes on the Balance Sheet. These amounts will be recognized as revenues in the Statement of Income in the periods they are billable to customers.
3. Accounts Receivable
Accumulated Provision for Uncollectible Accounts
The following table presents the rollforward of Accumulated Provision for Uncollectible Accounts on Customer Accounts Receivable (Account 144).
Year Ended December 31, 2023
Balance as of December 31, 2022$59 
Plus: Current period provision for uncollectible accounts(a)
53 
Less: Write-offs, net of recoveries(b)
43 
Balance as of December 31, 2023$69 
Year Ended December 31, 2022
Balance as of December 31, 2021$73 
Plus: Current period provision for uncollectible accounts29 
Less: Write-offs, net of recoveries43 
Balance as of December 31, 2022$59 
__________
(a)The change in the current period provision for expected credit losses is primarily a result of increased receivable balances.
(b)Recoveries were not material to ComEd.

The following table presents the rollforward of Accumulated Provision for Uncollectible Accounts on Other Accounts Receivable (Account 144).
Year Ended December 31, 2023
Balance as of December 31, 2022$17 
Plus: Current period provision for uncollectible accounts
Less: Write-offs, net of recoveries(a)
Balance as of December 31, 2023$17 

Year Ended December 31, 2022
Balance as of December 31, 2021$17 
Plus: Current period benefit for uncollectible accounts
Less: Write-offs, net of recoveries
Balance as of December 31, 2022$17 
__________
(a) Recoveries were not material to ComEd.

Accrued Utility Revenues
ComEd accrued $351 million and $223 million of unbilled revenues as of December 31, 2023 and December 31, 2022, respectively, in Account 173, Accrued Utility Revenues.

Purchase of Customer and Other Accounts Receivable

ComEd is required under legislation and regulations in Illinois to purchase certain receivables from alternative retail electric suppliers that participate in its consolidated billing. The following table presents the total receivable ComEd purchased:

Year Ended December 31,
20232022
Total receivables purchased$942 $965 
4. Property, Plant, and Equipment
The following table presents the average service life for each asset category in number of years as of December 31, 2023:
Asset CategoryAverage Service Life (years)
Electric - transmission and distribution3-80
Other property, plant and equipment30-50
The following table presents the annual depreciation rates for each asset category:
Annual Depreciation Rates December 31, 2023December 31, 2022
Electric-transmission and distribution3.04%3.02%
Allowance for Funds Used During Construction (AFUDC)
The credits to AFUDC debt and equity were $72 million and $54 million for the years ended December 31, 2023 and 2022, respectively.
See Note 1 - Significant Accounting Policies for additional information regarding property, plant and equipment policies. See Note 10 - Debt and Credit Agreements for additional information regarding ComEd's property, plant and equipment subject to mortgage liens.
5. Asset Retirement Obligations
ComEd has AROs primarily associated with the abatement and disposal of equipment and buildings contaminated with asbestos and polychlorinated biphenyls (PCBs). See Note 1 — Significant Accounting Policies for additional information on ComEd’s accounting policy for AROs
The following table provides a rollforward of the non-nuclear AROs reflected on ComEd’s Balance Sheet from December 31, 2021 to December 31, 2023:
AROs at December 31, 2021 (Account 230)
$146 
Net increase due to changes in, and timing of, estimated future cash flows
Accretion expense(a)
Payments(2)
AROs at December 31, 2022 (Account 230)
$150 
Net increase due to changes in, and timing of, estimated future cash flows(3)
Accretion expense(a)
Payments(2)
AROs at December 31, 2023 (Account 230)
$151 
__________
(a)The majority of the accretion is recorded as an increase to a regulatory asset (Account 182.3, Other Regulatory Assets) due to the associated regulatory treatment.
6. Intangible Assets
ComEd’s gross amount of goodwill, accumulated impairment losses and carrying amount of goodwill were $4,608 million, $1,983 million and $2,625 million, respectively, for both December 31, 2023 and 2022. The gross amount reflects goodwill recorded in 2000 from the PECO/Unicom (predecessor parent company of ComEd) merger net of amortization, resolution of tax matters and other non-impairment related changes as allowed under previous authoritative guidance.
Goodwill is recorded in Account 114, Electric Plant Acquisition Adjustments and Account 115, Accumulated Provision for Amortization of Electric Plant Acquisition Adjustments, as approved by FERC (Docket No. AC01-38-000). Goodwill is not amortized, but is subject to an assessment for impairment at least annually, or more frequently if events occur or circumstances change that would more likely than not reduce the fair value of the ComEd reporting unit below its carrying amount. A reporting unit is an operating segment or one level below an operating segment (known as a component) and is the
level at which goodwill is assessed for impairment. A component of an operating segment is a reporting unit if the component constitutes a business for which discrete financial information is available and its operating results are regularly reviewed by segment management. ComEd has a single operating segment. There is no level below this operating segment for which operating results are regularly reviewed by segment management. Therefore, ComEd’s operating segment is considered its only reporting unit.
Entities assessing goodwill for impairment have the option of first performing a qualitative assessment to determine whether a quantitative assessment is necessary. As part of the qualitative assessments, ComEd evaluates, among other things, management's best estimate of projected operating and capital cash flows for their businesses, outcomes of recent regulatory proceedings, changes in certain market conditions, including the discount rate and regulated utility peer EBITDA multiples, and the passing margin from its last quantitative assessments performed. If an entity bypasses the qualitative assessment, a quantitative, fair value-based assessment is performed, which compares the fair value of the reporting unit to its carrying amount, including goodwill. If the carrying amount of the reporting unit exceeds its fair value, the entity recognizes an impairment charge, which is limited to the amount of goodwill.
Application of the goodwill impairment assessment requires management judgment, including the identification of reporting units and determining the fair value of the reporting unit, which management estimates using a weighted combination of a discounted cash flow analysis and a market multiples analysis. Significant assumptions used in these fair value analyses include discount and growth rates, utility sector market performance and transactions, projected operating and capital cash flows for ComEd's business and the fair value of debt.
2023 and 2022 Goodwill Impairment Assessment. ComEd qualitatively determined that it was more likely than not that the fair value of its reporting unit exceeded the carrying value and, therefore, did not perform quantitative assessments as of November 1, 2023 and 2022. On December 14, 2023, due to the issuance of the ICC's final order rejecting ComEd’s proposed Grid Plan and establishing retail rates for 2024-2027 as further discussed in Note 2 - Regulatory Matters, Exelon’s stock price decreased approximately 10% triggering an interim quantitative assessment for potential goodwill impairment at ComEd. ComEd performed a quantitative assessment as of December 31, 2023, comparing the estimated fair value of ComEd to its carrying value, and determined there was no indication of goodwill impairment
While the annual assessments indicated no impairments, certain assumptions used to estimate reporting unit fair values are highly sensitive to changes. Adverse regulatory actions or changes in significant assumptions could potentially result in future impairments of ComEd's goodwill, which could be material.
7. Income Taxes
Components of Income Tax Expense or Benefit
Income tax expense (benefit) from continuing operations is comprised of the following components:
For the Year Ended December 31,
20232022
Included in operations:
Federal
   Current$136 $28 
   Deferred39 118 
   Investment tax credit amortization(1)(1)
State
   Current(10)(6)
   Deferred150 124 
Total (Accounts 409.1, 409.2, 410.1, 411.1, 411.4)$314 $263 
The effective income tax rate from continuing operations varies from the U.S. Federal statutory rate principally due to the following:
For the Year Ended December 31,
20232022
U.S. Federal statutory rate21.0 %21.0 %
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit7.8 7.9 
Amortization of investment tax credit, including deferred taxes on basis difference(0.1)(0.1)
Plant basis differences(0.4)(0.6)
Production tax credits and other credits (0.4)(0.3)
Excess deferred tax amortization(5.4)(5.6)
Other(0.2)— 
Effective income tax rate22.3 %22.3 %
The tax effects of temporary differences, which give rise to significant portions of the deferred tax assets and liabilities, as of December 31, 2023 and 2022 are presented below:
20232022
Deferred tax liabilities, net:
Plant basis differences$(4,983)$(4,821)
Derivative financial instruments37 23 
Deferred pension and post-retirement obligation(299)(300)
Deferred debt refinancing costs(5)(5)
Regulatory(405)(131)
Corporate alternative minimum tax118 — 
Other, net226 222 
Deferred income tax liabilities, net (Accounts 190, 282 and 283)$(5,311)$(5,012)
Unamortized investment tax credits (Account 255)(7)(8)
Total deferred income tax liabilities, net and unamortized investment tax credits$(5,318)$(5,020)
The following table provides ComEd's carryforwards as of December 31, 2023:
As of December 31, 2023
Federal
Minimum tax credit carryforward(a)
$118 
__________
(a)The Corporate Alternative Minimum Tax credit carryfoward has an indefinite carryforward period.
Tabular reconciliation of unrecognized tax benefits
The following table provides a GAAP reconciliation of ComEd’s unrecognized tax benefits as of December 31, 2023 and 2022:
Unrecognized tax benefits at January 1, 2022$15 
Changes to positions that only affect timing(1)
Increases based on tax positions related to 2022
Increases based on tax positions prior to 2022
Unrecognized tax benefits at December 31, 2022
$16 
  
Unrecognized tax benefits at January 1, 2023$16 
Changes to positions that only affect timing(1)
Increases based on tax positions related to 2023
Increases based on tax positions prior to 2023(8)
Unrecognized tax benefits at December 31, 2023
$

Recognition of unrecognized tax benefits

As of December 31, 2023 and December 31, 2022, ComEd has $6 million and $5 million, respectively, of unrecognized tax benefits that, if recognized, would decrease the effective tax rate.
Reasonably possible the total amount of unrecognized tax benefits could significantly increase or decrease within 12 months after the reporting date
As of December 31, 2023, ComEd has no unrecognized tax benefits that could significantly decrease within the 12 months after the reporting date.
Total amounts of interest and penalties recognized
As of December 31, 2023 and December 31, 2022, ComEd has accrued interest of $1 million and $1 million, respectively, and no penalties related to income tax positions.
Description of tax years that remain subject to examination by major jurisdiction
 Open Years
Federal consolidated income tax returns2010-2022
Illinois unitary corporate income tax returns2012-2022
Other Tax Matters
Corporate Alternative Minimum Tax
On August 16, 2022, the IRA was signed into law and implemented a new corporate alternative minimum tax (CAMT) that imposes a 15% tax on modified GAAP net income. Corporations are entitled to a tax credit (minimum tax credit) to the extent the CAMT liability exceeds the regular tax liability. This amount can be carried forward indefinitely and used in future years when regular tax exceeds the CAMT.

Based on the existing statue, ComEd will be subject to and will report the CAMT on a separate Registrant basis in the Consolidated Statements of Operations and Comprehensive Income and the Consolidated Balance Sheets. The deferred tax asset related to the minimum tax credit carryforward will be realized to the extent ComEd’s consolidated deferred tax liabilities exceed the minimum tax credit carryforward. ComEd’s deferred tax liabilities are expected to exceed the minimum tax credit carryforward for the foreseeable future and thus no valuation allowance is required. ComEd is continuing to assess the financial statement impacts of the IRA and will update estimates based on future guidance issued by the U.S. Treasury.

Long-Term Marginal State Income Tax Rate

Quarterly, Exelon reviews and updates its marginal state income tax rates for changes in state apportionment. ComEd remeasures its existing deferred income tax balances to reflect the changes in marginal rates, which results in either an increase or decrease to their net deferred income tax liability balances. ComEd records corresponding regulatory liabilities or assets to the extent such amounts are probable of settlement or recovery through customer rates and an adjustment to income tax expense for all other amounts. There were no adjustments to ComEd's deferred income tax liability balance for the years ended December 31, 2023 and 2022.
Allocation of Tax Benefits
ComEd is party to an agreement with Exelon and other subsidiaries of Exelon that provides for the allocation of consolidated tax liabilities and benefits (Tax Sharing Agreement). The Tax Sharing Agreement provides that each party is allocated an amount of tax similar to that which would be owed had the party been separately subject to tax. In addition, any net federal and state benefits attributable to Exelon is reallocated to ComEd and the other Registrants. That allocation is treated as a contribution to the capital of the party receiving the benefit.

ComEd recorded a federal tax benefit allocation from Exelon under the Tax Sharing Agreement as of December 31, 2023 of $12 million. ComEd did not record a federal tax benefit allocation from Exelon under the Tax Sharing Agreement as of December 31, 2022.
8. Retirement Benefits
Defined Benefit Pension and Other Postretirement Employee Benefits
Effective, February 1, 2022, in connection with the separation, pension and other postretirement employee benefits (OPEB) obligations and assets for current and former employees of the Constellation business and certain other former employees of Exelon and its subsidiaries transferred to pension and OPEB plans and trusts maintained by Constellation or its subsidiaries.
As a result of the separation, Exelon restructured certain of its qualified pension plans. Pension obligations and assets for current and former employees continuing with Exelon and who were participants in the Exelon Employee Pension Plan for Clinton, TMI, and Oyster Creek, and Pension Plan of Constellation Energy Nuclear Group, LLC, were merged into the Pension Plan of Constellation Energy Group, Inc., which was subsequently renamed, Exelon Pension Plan (EPP). Exelon employees who participated in these plans prior to the separation now participate in the EPP. The merging of the plans did not change the benefits offered to the plan participants and, this, had no impact on Exelon's pension obligations.
The listing below shows the pension and OPEB plans in which ComEd employees participated as of December 31, 2023:
Name of Plan(a):
Qualified Pension Plans:
Exelon Corporation Retirement Program
Exelon Corporation Pension Plan for Bargaining Unit Employees

Non-Qualified Pension Plans:
Exelon Corporation Supplemental Pension Benefit Plan and 2000 Excess Benefit Plan
Exelon Corporation Supplemental Management Retirement Plan
OPEB Plans:
Exelon Corporation Health Care Program
Exelon Corporation Employees' Life Insurance Plan
Exelon Corporation Health Reimbursement Arrangement Plan
__________
(a)Employees generally remain in their legacy benefit plans when transferring between operating companies.

Cost Allocation to ComEd
ComEd accounts for its participation in Exelon’s pension and OPEB plans by applying multi-employer accounting. Components of pension and OPEB costs and contributions have been, and will continue to be, allocated to ComEd based on both active and retired employee participation in each plan.
The amounts below represent ComEd's allocated portion of the pension and OPEB plan costs which were included in Operating expenses (Account 401) within ComEd's Statement of Income and Utility Plant (Account 101-106, 114) within ComEd's Balance Sheet for the years ended December 31, 2023 and 2022:
20232022
Pension and OPEB$26 $60 
Contributions
The following table provides ComEd's contribution to the pension and OPEB plans for the years ended December 31, 2023 and 2022:
20232022
Pension$24 $176 
OPEB17 
Management considers various factors when making pension funding decisions, including actuarially determined minimum contribution requirements under ERISA, contributions required to avoid benefit restrictions and at-risk status as defined by the Pension Protection Act of 2006 (the Act), management of the pension obligation and regulatory implications. The Act requires the attainment of certain funding levels to avoid benefit restrictions (such as an inability to pay lump sums or to accrue benefits prospectively), and at-risk status (which triggers higher minimum contribution requirements and participant notification). The projected contributions below reflect a funding strategy to make annual contributions with the objective of achieving 100% funded status on an accumulated benefit obligation (ABO) basis over time. This level funding strategy helps minimize volatility of future period required pension contributions. Unlike the qualified pension plans, Exelon’s non-qualified pension plans are not funded, given that they are not subject to statutory minimum contribution requirements.
While OPEB plans are also not subject to statutory minimum contribution requirements, Exelon does fund certain of its plans. For Exelon's funded OPEB plans, contributions generally equal accounting costs, however, Exelon’s management has historically considered several factors in determining the level of contributions to its OPEB plans, including liabilities management, levels of benefit claims paid, and regulatory implications (amounts deemed prudent to meet regulatory expectations and best assure continued rate recovery). The amounts below include benefit payments related to unfunded plans.
The following table provides ComEd's planned contributions to the qualified pension plans, planned benefit payments to non-qualified pension plans, and planned contributions to OPEB plans in 2024.
Qualified Pension Plans Non-Qualified Pension Plans OPEB
Planned contributions$$$18 
Defined Contribution Savings Plan
ComEd participates in various 401(k) defined contribution savings plans that are sponsored by Exelon. The plans are qualified under applicable sections of the IRC and allow employees to contribute a portion of their pre-tax and/or after-tax income in accordance with specified guidelines. ComEd matches a percentage of the employee contributions up to certain limits. The following table presents the employer contributions and employer matching contributions to the savings plans during the years ended December 31, 2023 and 2022:
20232022
Savings plan matching contributions$47 $39 
9. Derivative Financial Instruments
ComEd uses derivative instruments to manage commodity price risk related to ongoing business operations. ComEd does not execute derivatives for speculative or proprietary trading purposes.
Authoritative guidance requires that derivative instruments be recognized as either assets or liabilities at fair value, with changes in fair value of the derivative recognized in earnings immediately. Other accounting treatments are available through special election and designation, provided they meet specific, restrictive criteria both at the time of designation and on an ongoing basis. These alternative permissible accounting treatments include Normal Purchase Normal Sale (NPNS), cash flow hedges and fair value hedges. All derivative economic hedges related to commodities, referred to as economic hedges, are recorded at fair value through earnings and offset by a corresponding regulatory asset or liability. For all NPNS derivative instruments, accounts receivable or accounts payable are recorded when derivatives settle and revenue or expense is recognized in earnings as the underlying physical commodity is sold or consumed.
ComEd’s use of cash collateral is generally unrestricted unless ComEd is downgraded below investment grade.
Commodity Price Risk
ComEd employs established policies and procedures to manage its risk associated with market fluctuations in commodity prices by entering into physical and financial derivative contracts, which are either determined to be non-derivative or classified as economic hedges.
ComEd procures electric supply through a competitive procurement process approved by the ICC. ComEd’s hedging programs are intended to reduce exposure to energy price volatility and have no direct earnings impact as the costs are fully recovered from customers through regulatory-approved recovery mechanisms. The following table provides a summary of ComEd's primary derivative hedging instruments, listed by commodity and accounting treatment.
CommodityAccounting TreatmentHedging Instrument
ElectricityNPNSFixed price contracts based on all requirements in the IPA procurement plans.
Electricity
Changes in fair value of economic hedge recorded to an offsetting regulatory asset or liability(a)
20-year floating-to-fixed energy swap contracts beginning June 2012 based on the renewable energy resource procurement requirements in the Illinois Settlement Legislation of approximately 1.3 million MWhs per year.
__________
(a)See Note 2 - Regulatory Matters for additional information
The following table provides a summary of the derivative fair value balances recorded by ComEd as of December 31, 2023 and 2022:
December 31, 2023December 31, 2022
Mark-to-market derivative liabilities - current (Account 242)
$(27)$(5)
Mark-to-market derivative liabilities - noncurrent (Account 253)
(106)(79)
Total mark-to-market derivative liabilities$(133)$(84)
Credit Risk
ComEd would be exposed to credit-related losses in the event of non-performance by counterparties on executed derivative instruments. The credit exposure of derivative contracts, before collateral, is represented by the fair value of contracts at the reporting date.
ComEd has contracts to procure electric supply that provide suppliers with a certain amount of unsecured credit. If the exposure on the supply contract exceeds the amount of unsecured credit, the suppliers may be required to post collateral. The net credit exposure is mitigated primarily by the ability to recover procurement costs through customer rates. As of December 31, 2023 and 2022, the amount of cash collateral held with external counterparties were $146 million and $77 million, respectively, which is recorded in Miscellaneous Current and Accrued Liabilities in the Balance Sheet (Account 242).
ComEd's electric supply procurement contracts do not contain provisions that would require them to post collateral.
10. Debt and Credit Agreements
Short-Term Borrowings
ComEd meets its short-term liquidity requirements primarily through the issuance of commercial paper. ComEd may use its credit facilities for general corporate purposes, including meeting short-term funding requirements and the issuance of letters of credit.
Commercial Paper
The following table reflects ComEd's commercial paper programs supported by the revolving credit agreements as of December 31, 2023 and 2022:
Credit Facility Size as of December 31,Outstanding Commercial Paper as of December 31,Average Interest Rate on Commercial Paper Borrowings for the Year Ended December 31,
2023(a)
2022(a)
2023202220232022
$1,000 $1,000 $202 $427 5.53 %4.71 %
__________
(a)Excludes credit facility agreements arranged at minority and community banks. See below for additional information.
In order to maintain its commercial paper program in the amounts indicated above, ComEd must have credit facilities in place, at least equal to the amount of its commercial paper program. ComEd does not issue commercial paper in an aggregate amount exceeding the then available capacity under its credit facility.
As of December 31, 2023, ComEd had the following aggregate bank commitments, credit facility borrowings, and available capacity under its credit facility:
Available Capacity as of December 31, 2023
Facility Type
Aggregate Bank Commitment
Facility DrawsOutstanding Letters of CreditActualTo Support Additional Commercial Paper
Syndicated Revolver $1,000 $— $10 $990 $778 
The following table reflects ComEd's credit facility agreements arranged at minority and community banks as of December 31, 2023 and 2022. These are excluded from the Maximum Program Size and Aggregate Bank Commitment amounts within the two tables above and the facilities are solely used to issue letters of credit.
Aggregate Bank Commitments(a)
Outstanding Letters of Credit
2023202220232022
404077
__________
(a)These facilities were entered into on October 6, 2023 and expire October, 4, 2024.
Short-Term Loan Agreements
On October 4, 2022, ComEd entered into a 364-day term loan agreement for $150 million with a variable rate equal to Secured Overnight Financing Rate (SOFR) plus 0.75% and an expiration date of October 3, 2023. The proceeds from this loan were used to repay outstanding commercial paper obligations. The loan agreement is reflected in ComEd's Balance Sheet within Notes Payable (Account 231). The balance of the loan was repaid on January 13, 2023 in conjunction with the $400 million and $575 million First Mortgage Bond agreements that were entered into on January 3, 2023.
On May 9, 2023, ComEd entered into a 364-day term loan for $400 million with a variable rate equal to SOFR plus 1.00% and an expiration date of May 7, 2024. The proceeds from this loan were used to repay outstanding commercial paper obligations and for general corporate purposes. The loan agreement is reflected in ComEd's Balance Sheets within Notes Payable (Account 231).
Revolving Credit Agreements
On February 1, 2022, ComEd entered into a new 5-year revolving credit facility that replaced its existing syndicated revolving credit facility. The credit agreement has an aggregate bank commitment of $1 billion and an interest rate of SOFR plus 1.00%.
Borrowings under ComEd’s revolving credit agreements bear interest at a rate based upon either the prime rate or a SOFR-based rate, plus an adder based upon ComEd’s credit rating. ComEd has an adder of 0 basis points for prime based borrowings and 100 basis points for SOFR-based borrowings. If ComEd loses its investment grade rating, the maximum adders for prime rate borrowings and SOFR-based rate borrowings would be 65 basis points and 165 basis points, respectively. The credit agreements also require ComEd to pay a facility fee based upon the aggregate commitments. The fee varies depending upon the credit rating of ComEd. ComEd had no outstanding amounts on the revolving credit facilities as of December 31, 2023.
Long-Term Debt
The following tables present the outstanding long-term debt at ComEd as of December 31, 2023 and 2022:
December 31,
RatesMaturity Date20232022
Long-term debt
First Mortgage Bonds:
Fixed rates (Account 221)(a)
2.20 - 6.45%2024 - 2053$11,603 $10,629 
Notes payable and other (Accounts 224, 227)
7.49%2053
Total long-term debt$11,611 $10,637 
Unamortized debt discount and premium, net (Account 225 and 226)(28)(27)
Long-term debt$11,583 $10,610 
Long-term debt to financing trusts(b)
Subordinated debentures to ComEd Financing III (Account 223)6.35%2033$206 $206 
__________
(a)Substantially all of ComEd’s assets other than expressly excepted property are subject to the lien of its mortgage indenture.
(b)Amount owed to this financing trust is recorded as Long-term debt to financing trust within ComEd's Balance Sheet.
The following table presents the long-term debt that was issued on January 10, 2023:
TypeInterest
Rate
MaturityAmountUse of Proceeds
First Mortgage Bonds Series 1344.90 %February 1, 2023$400 Repay outstanding commercial paper obligations, to repay a $150 million term load with U.S. Bank National Association and to fund other general corporate purposes
First Mortgage Bonds Series 1355.30 %February 1, 2053575 Repay outstanding commercial paper obligations, to repay a $150 million term loan with U.S. Bank National Association and to fund other general corporate purposes
Long-term debt maturities at ComEd in the periods 2024 through 2028 and thereafter are as follows:
Year
2024$250 
2025— 
2026500 
2027350 
2028550 
Thereafter10,167 
(a)
Total$11,817 
________
(a)Includes $206 million due to ComEd financing trust.

Debt Covenants
As of December 31, 2023, the ComEd is in compliance with debt covenants.
11. Fair Value of Financial Assets and Liabilities
ComEd measures and classifies fair value measurements in accordance with the hierarchy as defined by authoritative guidance. The hierarchy prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:
Level 1 — quoted prices (unadjusted) in active markets for identical assets or liabilities that ComEd has the ability to liquidate as of the reporting date.
Level 2 — inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.
Level 3 — unobservable inputs, such as internally developed pricing models or third-party valuations for the asset or liability due to little or no market activity for the asset or liability.
Fair Value of Financial Liabilities Recorded at Amortized Cost
The following tables present the carrying amounts and fair values of ComEd's short-term liabilities, long-term debt, and trust preferred securities (long-term debt to financing trusts) as of December 31, 2023 and 2022. ComEd has no financial liabilities classified as Level 1 or measured using the NAV practical expedient.
The carrying amounts of ComEd's short-term liabilities as presented on ComEd's Balance Sheet are representative of their fair value (Level 2) because of the short-term nature of these instruments.
December 31, 2023December 31, 2022
Carrying AmountFair ValueCarrying AmountFair Value
Level 1Level 2Level 3TotalLevel 1Level 2Level 3Total
Long-term debt (Accounts 221, 224-227)(a)
$11,583 $— $10,210 $— $10,210 $10,610 $— $9,006 $— $9,006 
Long-term debt to financing trust (Account 223)206 — — 208 208 206 — — 204 204 
(a) Includes unamortized debt discount and premium, net, and purchase accounting fair value adjustments which are not fair valued. Refer to Note 10 - Debt and Credit Agreements.
ComEd uses the following methods and assumptions to estimate fair value of financial liabilities recorded at carrying cost:
TypeLevelValuation
Long-Term Debt, including amounts due within one year
Taxable Debt Securities2The fair value is determined by a valuation model that is based on a conventional discounted cash flow methodology and utilizes assumptions of current market pricing curves. ComEd obtains credit spreads based on trades of existing ComEd debt securities as well as other issuers in the utility sector with similar credit ratings. The yields are then converted into discount rates of various tenors that are used for discounting the respective cash flows of the same tenor for each bond or note.
Long-Term Debt to Financing Trusts
Long-Term Debt to Financing Trusts3Fair value is based on publicly traded securities issued by the financing trusts. Due to low trading volume of these securities and qualitative factors, such as market conditions, investor demand, and circumstances related to each issue, this debt is classified as Level 3..
Recurring Fair Value Measurements
The following table presents assets and liabilities measured and recorded at fair value on ComEd’s Balance Sheets on a recurring basis and their level within the fair value hierarchy as of December 31, 2023 and 2022. ComEd has no financial assets or liabilities measured using the NAV practical expedient:
December 31, 2023Level 1Level 2Level 3Total
Assets
Cash equivalents (Accounts 132-134, 136, and 186)(a)
$453 $— $— $453 
Total assets453 — — 453 
Liabilities
Deferred compensation obligation (Accounts 228.3, 242)— (8)— (8)
Commodity derivative liabilities(b) (Accounts 242, 253)
— — (133)(133)
Total liabilities— (8)(133)(141)
Total net assets (liabilities)$453 $(8)$(133)$312 
December 31, 2022Level 1Level 2Level 3Total
Assets
Cash equivalents (Accounts 132-134, 136, and 186)(a)
$392 $— $— $392 
Total assets392 — — 392 
Liabilities
Deferred compensation obligation (Accounts 228.3, 242)— (8)— (8)
Commodity liabilities(b) (Accounts 242, 253)
— — (84)(84)
Total liabilities— (8)(84)(92)
Total net assets (liabilities)$392 $(8)$(84)$300 
__________
(a)ComEd excludes cash of $46 million and $11 million as of December 31, 2023 and 2022, respectively, and restricted cash of $147 million and $76 million as of December 31, 2023 and 2022, respectively, and includes long-term restricted cash of $174 million and $117 million as of December 31, 2023 and 2022, respectively, which is reported in Other deferred debits in the Balance Sheet. The excluded cash balance as of December 31, 2022 has been updated from the amount previously disclosed in the 2022 FERC Form No. 1.
(b)The Level 3 balance consists of the current and noncurrent liability of $27 million and $106 million, respectively, as of December 31, 2023, and $5 million and $79 million, respectively, as of December 31, 2022 related to floating-to-fixed energy swap contracts with unaffiliated suppliers.
Reconciliation of Level 3 Assets and Liabilities
The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis during the years ended December 31, 2023 and 2022:
Mark-to-Market Derivatives
Balance as of December 31, 2022$(84)
Total realized / unrealized gains (losses) included in regulatory assets/liabilities(a)
(49)
Balance as of December 31, 2023 (Accounts 242, 253)$(133)
(b)
Mark-to-Market Derivatives
Balance as of December 30, 2021$(219)
Total realized / unrealized gains (losses) included in regulatory assets/liabilities(a)
135 
Balance as of December 31, 2022 (Accounts 242, 253)$(84)
__________
(a)Includes $83 million of decreases in fair value and an increase for realized losses due to settlements of $34 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the year ended December 31, 2023. Includes $136 million of increases in fair value and a decrease for realized losses due to settlements of $1 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the year ended December 31, 2022.
(b)The balance consists of a current (Account 242) and noncurrent (Account 253) liability of $27 million and $106 million, respectively, as of December 31, 2023.
Valuation Techniques Used to Determine Fair Value
Cash Equivalents. Investments with original maturities of three months or less when purchased, including mutual and money market funds, are considered cash equivalents. The fair values are based on observable market prices and, therefore, are included in the recurring fair value measurements hierarchy as Level 1.
Deferred Compensation Obligations. ComEd’s deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. ComEd includes such plans in other current and noncurrent liabilities in its Balance Sheet. The value of ComEd’s deferred compensation obligations is based on the market value of the participants’ notional investment accounts. The underlying notional investments are comprised primarily of equities, mutual funds, commingled funds, and fixed income securities, which are based on directly and indirectly observable market prices. Since the deferred compensation obligations themselves are not exchanged in an active market, they are categorized as Level 2 in the fair value hierarchy.
The value of certain employment agreement obligations (which are included with the Deferred Compensation Obligation in the tables above) are based on a known and certain stream of payments to be made over time and are categorized as Level 2 within the fair value hierarchy.
Commodity Derivatives. On December 17, 2010, ComEd entered into several 20-year floating to fixed energy swap contracts with unaffiliated suppliers for the procurement of long-term renewable energy and associated RECs. Delivery under the contracts began in June 2012. The fair value of these swaps has been designated as a Level 3 valuation due to the long tenure of the positions and the internal modeling assumptions. The modeling assumptions include using forward power prices. See Note 9 — Derivative Financial Instruments for additional information on mark-to-market derivatives. .
The following table presents the significant inputs to the forward curve used to value ComEd’s position:
Type of tradeFair Value as of December 31, 2023Valuation TechniqueUnobservable Input2023 Range & Arithmetic Average
Commodity derivatives$(133)Discounted Cash Flow
Forward power price(a)
$30.27$73.71$43.35
Type of tradeFair Value as of December 31, 2022Valuation TechniqueUnobservable Input2022 Range & Arithmetic Average
Commodity derivatives$(84)Discounted Cash Flow
Forward power price(a)
$34.78$75.71$48.44
__________
(a)An increase to the forward power price would increase the fair value.
12. Commitments and Contingencies
Commercial Commitments
ComEd's commercial commitments as of December 31, 2023, representing commitments potentially triggered by future events, were as follows:
Expiration within
Total202420252026202720282029 and beyond
Letters of credit(a)
$17 $15 $$— $— $— $— 
Surety bonds(b)
46 46 — — — — — 
Financing trust guarantees(c)
200 — — — — — 200 
Total commercial commitments$263 $61 $$— $— $— $200 

__________
(a)ComEd maintains non-debt letters of credit to provide credit support for certain transactions as requested by third parties.
(b)Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. Historically, payments under the guarantees have not been made and the likelihood of payments being required is remote.
(c)Reflects guarantee of ComEd securities held by ComEd Financing III.
Environmental Remediation Matters
General. ComEd’s operations have in the past, and may in the future, require substantial expenditures to comply with environmental laws. Additionally, under federal and state environmental laws, ComEd is generally liable for the costs of remediating environmental contamination of property now or formerly owned by them and of property contaminated by hazardous substances generated by them. ComEd owns or leases a number of real estate parcels, including parcels on which its operations or the operations of others may have resulted in contamination by substances that are considered hazardous
under environmental laws. In addition, ComEd is currently involved in a number of proceedings relating to sites where hazardous substances have been deposited and may be subject to additional proceedings in the future. Unless otherwise disclosed, ComEd cannot reasonably estimate whether it will incur significant liabilities for additional investigation and remediation costs at these or additional sites identified by ComEd, environmental agencies or others, or whether such costs will be recoverable from third parties, including customers. Additional costs could have a material, unfavorable impact on ComEd's financial statements.
Manufactured Gas Plant (MGP) Sites. ComEd has identified sites where former MGP activities have or may have resulted in actual site contamination. For some sites, there are additional potentially responsible parties that may share responsibility for the ultimate remediation of each location. ComEd has 17 sites that are currently under some degree of active study and/or remediation. ComEd expects the majority of the remediation at these sites to continue through at least 2031.
The historical nature of the MGP sites and the fact that many of the sites have been buried and built over, impacts the ability to determine a precise estimate of the ultimate costs prior to initial sampling and determination of the exact scope and method of remedial activity. Management determines its best estimate of remediation costs using all available information at the time of each study, including probabilistic and deterministic modeling, and the remediation standards currently required by the applicable state environmental agency. Prior to completion of any significant clean up, each site remediation plan is approved by the appropriate state environmental agency.
ComEd, pursuant to an ICC order, is currently recovering environmental remediation costs of former MGP facility sites through customer rates.
In 2023, ComEd completed an annual study of its future estimated MGP remediation requirements. The study resulted in a $25 million increase to the environmental liability and related regulatory asset. The increase was primarily due to increased costs due to inflation and changes in remediation plans.
As of December 31, 2023 and 2022, ComEd had accrued the following undiscounted amounts for environmental liabilities in Account 228.4, Accumulated Miscellaneous Operating Provisions in its Balance Sheet:
Total Environmental Investigation and Remediation LiabilitiesPortion of Total Related to MGP Investigation and Remediation
December 31, 2023$303 $302 
December 31, 2022$325 $324 
Litigation and Regulatory Matters
Fund Transfer Restrictions. Under applicable law, ComEd can pay dividends only from retained, undistributed or current earnings. A significant loss recorded at ComEd may limit the dividends that can distribute to Exelon.
ComEd has agreed in connection with financings arranged through ComEd Financing III that it will not declare dividends on any shares of its capital stock in the event that: (1) it exercises its right to extend the interest payment periods on the subordinated debt securities issued to ComEd Financing III; (2) it defaults on its guarantee of the payment of distributions on the preferred trust securities of ComEd Financing III; or (3) an event of default occurs under the Indenture under which the subordinated debt securities are issued. No such event has occurred.
Deferred Prosecution Agreement (DPA) and Related Matters. Exelon and ComEd received a grand jury subpoena in the second quarter of 2019 from the United States Attorney's Office for the Northern District of Illinois (USAO) requiring production of information concerning their lobbying activities in the State of Illinois. On October 4, 2019, Exelon and ComEd received a second grand jury subpoena from the USAO requiring production of records of any communications with certain individuals and entities. On October 22, 2019, the SEC notified Exelon and ComEd that it had also opened an investigation into their lobbying activities. On July 17, 2020, ComEd entered into a DPA with the USAO to resolve the USAO investigation. Under the DPA, the USAO filed a single charge alleging that ComEd improperly gave and offered to give jobs, vendor subcontracts, and payments associated with those jobs and subcontracts for the benefit of the former Speaker of the Illinois House of Representatives and the Speaker’s associates, with the intent to influence the Speaker’s action regarding legislation affecting ComEd’s interests. The DPA provided that the USAO would defer any prosecution of such charge and any other criminal or civil case against ComEd in connection with the matters identified therein for a three-year period subject to certain obligations of ComEd, including payment to the U.S. Treasury of $200 million, which was paid in November 2020. Exelon was not made a party to the DPA, and therefore the investigation by the USAO into Exelon’s activities ended with no charges being brought against Exelon. The three-year term of the DPA ended on July 17, 2023, and on that same date the court granted the USAO’s motion to dismiss the pending charge against ComEd that had been deferred by the DPA.
On September 28, 2023, Exelon and ComEd reached a settlement with the Securities and Exchange Commission (SEC), concluding and resolving in its entirety the SEC investigation, which related to the conduct identified in the DPA that was
entered into by ComEd in July 2020 and successfully exited in July 2023. Under the terms of the settlement, Exelon agreed to pay a civil penalty of $46.2 million and Exelon and ComEd agreed to cease and desist from committing or causing any violations and any future violations of specified provisions of the federal securities laws and rules promulgated thereunder. Exelon recorded an accrual for the full amount of the penalty in the second quarter of 2023, which was reflected in Operating and maintenance expense within Exelon's Consolidated Statements of Operations and Comprehensive Income and in Accrued expenses on the Consolidated Balance Sheets. Exelon paid the civil penalty in full on October 4, 2023.

Subsequent to Exelon announcing the receipt of the subpoenas, various lawsuits were filed, and various demand letters were received, related to the subject of the subpoenas and the conduct described in the DPA and the SEC's investigation, including:

Four putative class action lawsuits against ComEd and Exelon were filed in federal court on behalf of ComEd customers in the third quarter of 2020 alleging, among other things, civil violations of federal racketeering laws. In addition, the Citizens Utility Board (CUB) filed a motion to intervene in these cases on October 22, 2020 which was granted on December 23, 2020. On September 9, 2021, the federal court granted Exelon’s and ComEd’s motion to dismiss and dismissed the plaintiffs’ and CUB’s federal law claim with prejudice. The federal court also dismissed the related state law claims made by the federal plaintiffs and CUB on jurisdictional grounds. Plaintiffs appealed dismissal of the federal law claim to the Seventh Circuit Court of Appeals. Plaintiffs and CUB also refiled their state law claims in state court and moved to consolidate them with the already pending consumer state court class action, discussed below. On August 22, 2022, the Seventh Circuit affirmed the dismissal of the consolidated federal cases in their entirety. The time to further appeal has passed and the Seventh Circuit’s decision is final.

Three putative class action lawsuits against ComEd and Exelon were filed in Illinois state court in the third quarter of 2020 seeking restitution and compensatory damages on behalf of ComEd customers. The cases were consolidated into a single action in October of 2020. In November 2020, CUB filed a motion to intervene in the cases pursuant to an Illinois statute allowing CUB to intervene as a party or otherwise participate on behalf of utility consumers in any proceeding which affects the interest of utility consumers. On November 23, 2020, the court allowed CUB’s intervention, but denied CUB's request to stay these cases. Plaintiffs subsequently filed a consolidated complaint, and ComEd and Exelon filed a motion to dismiss on jurisdictional and substantive grounds on January 11, 2021. Briefing on that motion was completed on March 2, 2021. The parties agreed, on March 25, 2021, along with the federal court plaintiffs discussed above, to jointly engage in mediation. The parties participated in a one-day mediation on June 7, 2021 but no settlement was reached. On December 23, 2021, the state court granted ComEd and Exelon’s motion to dismiss with prejudice. On December 30, 2021, plaintiffs filed a motion to reconsider that dismissal and for permission to amend their complaint. The court denied the plaintiffs' motion on January 21, 2022. Plaintiffs have appealed the court's ruling dismissing their complaint to the First District Court of Appeals. On February 15, 2022, Exelon and ComEd moved to dismiss the federal plaintiffs' refiled state law claims, seeking dismissal on the same legal grounds asserted in their motion to dismiss the original state court plaintiffs' complaint. The court granted dismissal of the refiled state claims on February 16, 2022. The original federal plaintiffs appealed that dismissal on February 18, 2022. The two state appeals were consolidated on March 21, 2022. On September 8, 2023, the Illinois appellate court affirmed the dismissal. Plaintiffs have asked the Illinois Supreme Court to grant them leave to further appeal, but such appeal is not allowed as a matter of right. Exelon and ComEd filed a response in opposition to the request for leave to further appeal on January 12, 2024.

On November 3, 2022, a plaintiff filed a putative class action complaint in Lake County, Illinois Circuit Court against ComEd and Exelon for unjust enrichment and deceptive business practices in connection with the conduct giving rise to the DPA. Plaintiff seeks an accounting and disgorgement of any benefits ComEd allegedly obtained from said conduct. Plaintiff served initial discovery requests on ComEd in December 2022, to which ComEd has responded. ComEd and Exelon filed a motion to dismiss the Complaint on February 3, 2023. On June 16, 2023, the court granted Exelon and ComEd's motion to dismiss the action with prejudice. Plaintiff filed its notice of appeal of that dismissal on July 17, 2023. Plaintiff's opening appellate brief was filed on October 19, 2023. ComEd and Exelon filed a response on January 2, 2024. Plaintiff filed its reply brief on February 2, 2024. With leave of court, Exelon and ComEd filed a sur-reply on February 14, 2024. The appellate court has set oral argument for April 3, 2024.

A putative class action lawsuit against Exelon and certain officers of Exelon and ComEd was filed in federal court in December 2019 alleging misrepresentations and omissions in Exelon’s SEC filings related to ComEd’s lobbying activities and the related investigations. The complaint was amended on September 16, 2020, to dismiss two of the original defendants and add other defendants, including ComEd. Defendants filed a motion to dismiss in November 2020. The court denied the motion in April 2021. On May 26, 2021, defendants moved the court to certify its order denying the motion to dismiss for interlocutory appeal. Briefing on the motion was completed in June 2021, and that motion was denied on January 28, 2022. In May 2021, the parties each filed respective initial discovery disclosures. On June 9, 2021, defendants filed their answer and affirmative defenses to the complaint and the parties engaged thereafter in discovery. On September 9, 2021, the U.S. government moved to intervene in the lawsuit and stay
discovery until the parties entered into an amendment to their protective order that would prohibit the parties from requesting discovery into certain matters, including communications with the U.S. government. The court ordered said amendment to the protective order on November 15, 2021 and discovery resumed. The court further amended the protective order on October 17, 2022 and extended it until May 15, 2023. Following mediation, the parties reached a settlement of the lawsuit, under which defendants agreed to pay plaintiffs $173 million. On May 26, 2023, plaintiffs filed a motion for preliminary approval of the settlement, which the court granted on June 9, 2023. The court granted final settlement approval on September 7, 2023. The settlement was fully covered by insurance and has been paid in full.

Several shareholders have sent letters to the Exelon Board of Directors since 2020 demanding, among other things, that the Exelon Board of Directors investigate and address alleged breaches of fiduciary duties and other alleged violations by Exelon and ComEd officers and directors related to the conduct described in the DPA. In the first quarter of 2021, the Exelon Board of Directors appointed a Special Litigation Committee (SLC) consisting of disinterested and independent parties to investigate and address these shareholders' allegations and make recommendations to the Exelon Board of Directors based on the outcome of the SLC's investigation. In July 2021, one of the demand letter shareholders filed a derivative action against current and former Exelon and ComEd officers and directors, and against Exelon, as nominal defendant, asserting the same claims made in its demand letter. On October 12, 2021, the parties to the derivative action filed an agreed motion to stay that litigation for 120 days in order to allow the SLC to continue its investigation, which the court granted. The stay has been extended several times. The parties participated in a mediation in February 2023, but the matter did not resolve at that time. On April 26 and May 1, 2023, two additional demand letter shareholders each filed a separate derivative lawsuit against current and former Exelon and ComEd officers and directors, and certain third parties, and against Exelon as nominal defendant, asserting claims similar to those made in their respective demand letters. On May 25, 2023, certain demand letter shareholders (Settling Shareholders) filed a separate derivative lawsuit against current and former Exelon and ComEd officers and directors, and against Exelon as nominal defendant, asserting claims similar to those made in their respective demand letters. The then pending derivative lawsuits were subsequently consolidated. On May 26, 2023, prior to lawsuit consolidation, the SLC filed a Notice of Determination and Intent to Seek Court Approval of Settlement (Notice of Determination). The Notice of Determination stated that, through mediation efforts, a settlement of the derivative claims had been approved by the SLC, the Independent Review Committee of the Board (which had been formed in the third quarter of 2022, to ensure the Board’s consideration of any SLC recommendations would be independent and objective), the Board, and the Settling Shareholders (the Settling Parties). The Notice of Determination further specified the process by which the Settling Parties would seek court approval of the proposed settlement and resolution and dismissal of all derivative claims and lawsuits, including any lawsuits or actions brought by demand letter shareholders who are not participating in the proposed settlement. In furtherance of the proposed settlement, on June 16, 2023, the SLC filed a motion for preliminary approval of the settlement, attaching the Stipulation and Agreement of Settlement (Stipulation), which contains the terms of the proposed settlement. The proposed settlement terms include but are not limited to: a payment of $40 million to Exelon by Exelon’s insurers of which $10 million constitutes the attorneys’ fee award to be paid to the Settling Shareholders’ counsel; various compliance and disclosure-related reforms; and certain changes in Board and Committee composition. On June 13, 2023, the non-settling derivative shareholders filed a motion asking the court to set a status conference to discuss lifting the discovery stay. On June 29, 2023, an additional shareholder filed a separate derivative lawsuit against current and former Exelon and ComEd officers and directors, and against Exelon as nominal defendant, asserting claims similar to those made in its demand letter. That lawsuit has been consolidated into the other pending derivative lawsuits. On June 30, 2023, the non-settling shareholders’ motion for status and the SLC’s motion for preliminary approval was heard by the court, during which the court set a briefing schedule on the appropriate standard for evaluating the settlement and the proper scope of requested discovery. Following briefing and a hearing, the court allowed the non-settling shareholders to seek certain, limited discovery, which the SLC, Independent Review Committee, and Exelon responded to on October 5, 2023. On October 11, 2023, an additional non-settling shareholder filed a separate derivative lawsuit against current and former Exelon and ComEd officers and directors, and against Exelon as a nominal defendant, asserting claims similar to those made in its demand letter. That lawsuit has been consolidated into the other pending derivative lawsuits. The SLC filed its renewed motion for preliminary approval on October 26, 2023, with supporting submissions filed by the Independent Review Committee, Exelon, and the settling shareholders on that same day. The non-settling plaintiffs filed a response to the renewed motion for preliminary approval and supporting submissions on November 29, 2023, and the SLC Independent Review Committee, Exelon and the Settling Shareholders filed their respective reply briefs on December 21, 2023. On January 16, 2024, the non-settling plaintiffs sought leave of court to file a sur-reply, which the court granted on January 18, 2024.

In August 2022, the ICC concluded its investigation initiated on August 12, 2021 into rate impacts of conduct admitted in the DPA, including the costs recovered from customers related to the DPA and Exelon's funding of the fine paid by ComEd. On August 17, 2022, the ICC issued its final order accepting ComEd's voluntary customer refund offer of approximately $38 million (of which about $31 million is ICC jurisdictional; the remaining balance is FERC jurisdictional) that resolves the
question of whether customer funds were used for DPA related activities. The customer refund includes the cost of every individual or entity that was either (i) identified in the DPA or (ii) identified by ComEd as an associate of the former Speaker of the Illinois House of Representatives in the ICC proceeding. The ICC’s DPA investigation is now closed. The ICC jurisdictional refund was made to customers during the April 2023 billing cycle, as required by the ICC. The FERC jurisdictional refund was included in ComEd's transmission formula rate update proceeding, filed on May 12, 2023. The filed transmission rate, inclusive of the FERC jurisdictional DPA refund, will appear on ComEd retail customers' bills for the June 2023 through May 2024 monthly billing periods, in the line designated as "Transmission Services Charge." The customer refund will not be recovered in rates or charged to customers and ComEd will not seek or accept reimbursement or indemnification from any source other than Exelon. An accrual for the amount of the customer refund has been recorded in Regulatory assets (account 182.3) and Regulatory liabilities (account 254) in Exelon’s and ComEd’s Consolidated Balance Sheets as of December 31, 2023.
General. ComEd is involved in various other litigation matters that are being defended and handled in the ordinary course of business. ComEd is also from time to time subject to audits and investigations by the FERC and other regulators. The assessment of whether a loss is probable or reasonably possible, and whether the loss or a range of loss is estimable, often involves a series of complex judgments about future events. ComEd maintains accruals for such losses that are probable of being incurred and subject to reasonable estimation. Management is sometimes unable to estimate an amount or range of reasonably possible loss, particularly where (1) the damages sought are indeterminate, (2) the proceedings are in the early stages, or (3) the matters involve novel or unsettled legal theories. In such cases, there is considerable uncertainty regarding the timing or ultimate resolution of such matters, including a possible eventual loss.
13. Shareholders' Equity
Common Stock Warrants (Account 201)
ComEd had 60,032 and 60,052 warrants outstanding to purchase ComEd common stock at December 31, 2023 and 2022, respectively. The warrants entitle the holders to convert such warrants into common stock of ComEd at a conversion rate of one share of common stock for three warrants. At December 31, 2023 and 2022, 20,011 and 20,017 shares of common stock, respectively, were reserved for the conversion of warrants.
Preferred and Preference Securities (Account 204)
At December 31, 2023 and 2022, ComEd had preferred securities and cumulative preference securities of 850,000 shares and 6,810,451 shares authorized, respectively, none of which were outstanding.
14. Supplemental Financial Information
Supplemental Statement of Income Information
The following table provides additional information about material items recorded in ComEd's Statement of Income for the years ended December 31, 2023 and 2022:
For the Year Ended December 31,
20232022
Taxes other than income (Accounts 408.1 and 408.2)
Utility(a)
$299 $306 
Property33 31 
Payroll31 28 
________
(a)ComEd’s utility taxes represent municipal and state utility taxes and gross receipts taxes related to its operating revenues. The offsetting collection of utility taxes from customers is recorded in revenues in ComEd's Statement of Income.
Supplemental Statement of Cash Flows Information
The following table provides additional information about ComEd's Statement of Cash Flows for the years ended December 31, 2023 and 2022:
For the Year Ended December 31,
20232022
Cash paid during the year
Interest (net of amount capitalized)
$441 $396 
Income Taxes (net of refunds)11 23 
Non-cash investing activities
Decrease in capital expenditures not paid$(10)$(20)
15. Related Party Transactions
Expenses from Generation
ComEd incurred expenses from transaction with the Generation affiliate as described in the footnote to the table below prior to the separation on February 1, 2022. Such expenses were primarily recorded as Purchased power from affiliates and an immaterial amount recorded as Operating and maintenance expense from affiliates at ComEd. Effective February 1, 2022, Generation is no longer considered a related party of ComEd.
ComEd's Purchased power from Generation are as follows:
For the Years Ended December 31,
2022
Expenses with Generation(a)
$59 
__________
(a) ComEd had an ICC approved RFP contract with Generation to provide a portion of ComEd's electric supply requirements. ComEd also purchased RECs and ZECs from Generation

Service Company Costs for Corporate Support

ComEd receives a variety of corporate support services from Exelon's Business Services Corporation (BSC). The following table presents the service company costs allocated to ComEd:
Operating and maintenance from affiliateCapitalized costs from affiliate
For the years ended December 31,As of December 31,
2023202220232022
BSC$353 $316 $307 $311 

Current Payables to affiliates
The following table presents ComEd's current Payables to affiliates:
As of December 31,
20232022
BSC$64 $66 
ComEd Financing III
ComEd of Indiana— 
Other
Total$73 $74 
Noncurrent Receivables from affiliates
The following table presents ComEd's noncurrent Receivables from affiliates:
For the Years Ended December 31,
2023
2022(a)
Other(a)
$$
__________
(a) The December 31, 2022 noncurrent receivables from affiliates balance was classified as both current and noncurrent receivables from affiliates in the 2022 Form 1 filed April 4, 2023. The December 31, 2022 balance has been corrected and the current receivables from affiliates table has been removed from the footnote above.
Long-term debt to financing trusts
ComEd has Long-term debt to the ComEd Financing III trust of $205 million as of both December 31, 2023 and 2022.


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
  1. Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate.
  2. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges.
  3. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote.
  4. Report data on a year-to-date basis.
Line No.
Item
(a)
Unrealized Gains and Losses on Available-For-Sale Securities
(b)
Minimum Pension Liability Adjustment (net amount)
(c)
Foreign Currency Hedges
(d)
Other Adjustments
(e)
Other Cash Flow Hedges Interest Rate Swaps
(f)
Other Cash Flow Hedges [Specify]
(g)
Totals for each category of items recorded in Account 219
(h)
Net Income (Carried Forward from Page 116, Line 78)
(i)
Total Comprehensive Income
(j)
1
Balance of Account 219 at Beginning of Preceding Year
2
Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3
Preceding Quarter/Year to Date Changes in Fair Value
4
Total (lines 2 and 3)
917,177,045
917,177,045
5
Balance of Account 219 at End of Preceding Quarter/Year
6
Balance of Account 219 at Beginning of Current Year
7
Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8
Current Quarter/Year to Date Changes in Fair Value
9
Total (lines 7 and 8)
1,094,078,343
1,094,078,343
10
Balance of Account 219 at End of Current Quarter/Year


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION

Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.

Line No.
Classification
(a)
Total Company For the Current Year/Quarter Ended
(b)
Electric
(c)
Gas
(d)
Other (Specify)
(e)
Other (Specify)
(f)
Other (Specify)
(g)
Common
(h)
1
UtilityPlantAbstract
UTILITY PLANT
2
UtilityPlantInServiceAbstract
In Service
3
UtilityPlantInServiceClassified
Plant in Service (Classified)
36,318,993,336
36,318,993,336
4
UtilityPlantInServicePropertyUnderCapitalLeases
Property Under Capital Leases
7,849,772
7,849,772
5
UtilityPlantInServicePlantPurchasedOrSold
Plant Purchased or Sold
6
UtilityPlantInServiceCompletedConstructionNotClassified
Completed Construction not Classified
1,124,503,119
1,124,503,119
7
UtilityPlantInServiceExperimentalPlantUnclassified
Experimental Plant Unclassified
8
UtilityPlantInServiceClassifiedAndUnclassified
Total (3 thru 7)
37,451,346,227
37,451,346,227
9
UtilityPlantLeasedToOthers
Leased to Others
10
UtilityPlantHeldForFutureUse
Held for Future Use
89,342,102
89,342,102
11
ConstructionWorkInProgress
Construction Work in Progress
1,395,544,738
1,395,544,738
12
UtilityPlantAcquisitionAdjustment
Acquisition Adjustments
2,774,314,255
2,774,314,255
13
UtilityPlantAndConstructionWorkInProgress
Total Utility Plant (8 thru 12)
41,710,547,322
41,710,547,322
14
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Accumulated Provisions for Depreciation, Amortization, & Depletion
11,713,097,084
11,713,097,084
15
UtilityPlantNet
Net Utility Plant (13 less 14)
29,997,450,238
29,997,450,238
16
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract
In Service:
18
DepreciationUtilityPlantInService
Depreciation
10,663,341,920
10,663,341,920
19
AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService
Amortization and Depletion of Producing Natural Gas Land and Land Rights
20
AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService
Amortization of Underground Storage Land and Land Rights
21
AmortizationOfOtherUtilityPlantUtilityPlantInService
Amortization of Other Utility Plant
900,380,549
900,380,549
22
DepreciationAmortizationAndDepletionUtilityPlantInService
Total in Service (18 thru 21)
11,563,722,469
11,563,722,469
23
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract
Leased to Others
24
DepreciationUtilityPlantLeasedToOthers
Depreciation
25
AmortizationAndDepletionUtilityPlantLeasedToOthers
Amortization and Depletion
26
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers
Total Leased to Others (24 & 25)
27
DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract
Held for Future Use
28
DepreciationUtilityPlantHeldForFutureUse
Depreciation
29
AmortizationUtilityPlantHeldForFutureUse
Amortization
30
DepreciationAndAmortizationUtilityPlantHeldForFutureUse
Total Held for Future Use (28 & 29)
31
AbandonmentOfLeases
Abandonment of Leases (Natural Gas)
32
AmortizationOfPlantAcquisitionAdjustment
Amortization of Plant Acquisition Adjustment
149,374,615
149,374,615
33
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Total Accum Prov (equals 14) (22,26,30,31,32)
11,713,097,084
11,713,097,084


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
  1. Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent.
  2. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No.
Description of item
(a)
Balance Beginning of Year
(b)
Changes during Year Additions
(c)
Changes during Year Amortization
(d)
Changes during Year Other Reductions (Explain in a footnote)
(e)
Balance End of Year
(f)
1
Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1)
2
Fabrication
3
Nuclear Materials
4
Allowance for Funds Used during Construction
5
(Other Overhead Construction Costs, provide details in footnote)
6
SUBTOTAL (Total 2 thru 5)
7
Nuclear Fuel Materials and Assemblies
8
In Stock (120.2)
9
In Reactor (120.3)
10
SUBTOTAL (Total 8 & 9)
11
Spent Nuclear Fuel (120.4)
12
Nuclear Fuel Under Capital Leases (120.6)
13
(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)
14
TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)
15
Estimated Net Salvage Value of Nuclear Materials in Line 9
16
Estimated Net Salvage Value of Nuclear Materials in Line 11
17
Est Net Salvage Value of Nuclear Materials in Chemical Processing
18
Nuclear Materials held for Sale (157)
19
Uranium
20
Plutonium
21
Other (Provide details in footnote)
22
TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21)


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
  1. Report below the original cost of electric plant in service according to the prescribed accounts.
  2. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric.
  3. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year.
  4. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments.
  5. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts.
  6. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of the prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year.
  7. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications.
  8. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages.
  9. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No.
Account
(a)
Balance Beginning of Year
(b)
Additions
(c)
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at End of Year
(g)
1
1. INTANGIBLE PLANT
2
(301) Organization
80,375
80,375
3
(302) Franchise and Consents
4
(303) Miscellaneous Intangible Plant
1,107,589,922
103,990,093
39,061,493
1,172,518,522
5
TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)
1,107,670,297
103,990,093
39,061,493
1,172,598,897
6
2. PRODUCTION PLANT
7
A. Steam Production Plant
8
(310) Land and Land Rights
9
(311) Structures and Improvements
10
(312) Boiler Plant Equipment
11
(313) Engines and Engine-Driven Generators
12
(314) Turbogenerator Units
13
(315) Accessory Electric Equipment
14
(316) Misc. Power Plant Equipment
15
(317) Asset Retirement Costs for Steam Production
16
TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)
17
B. Nuclear Production Plant
18
(320) Land and Land Rights
19
(321) Structures and Improvements
20
(322) Reactor Plant Equipment
21
(323) Turbogenerator Units
22
(324) Accessory Electric Equipment
23
(325) Misc. Power Plant Equipment
24
(326) Asset Retirement Costs for Nuclear Production
25
TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)
26
C. Hydraulic Production Plant
27
(330) Land and Land Rights
28
(331) Structures and Improvements
29
(332) Reservoirs, Dams, and Waterways
30
(333) Water Wheels, Turbines, and Generators
31
(334) Accessory Electric Equipment
32
(335) Misc. Power Plant Equipment
33
(336) Roads, Railroads, and Bridges
34
(337) Asset Retirement Costs for Hydraulic Production
35
TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)
36
D. Other Production Plant
37
(340) Land and Land Rights
38
(341) Structures and Improvements
39
(342) Fuel Holders, Products, and Accessories
40
(343) Prime Movers
41
(344) Generators
42
(345) Accessory Electric Equipment
43
(346) Misc. Power Plant Equipment
44
(347) Asset Retirement Costs for Other Production
44.1
(348) Energy Storage Equipment - Production
45
TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)
46
TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)
47
3. Transmission Plant
48
(350) Land and Land Rights
189,527,512
30
189,527,542
48.1
(351) Energy Storage Equipment - Transmission
49
(352) Structures and Improvements
758,230,883
36,060,175
4,984,080
789,306,978
50
(353) Station Equipment
2,965,570,121
181,414,030
5,183,058
201,282
3,142,002,375
51
(354) Towers and Fixtures
269,881,353
2,316,895
272,198,248
52
(355) Poles and Fixtures
964,651,855
16,883,156
178,897
981,356,114
53
(356) Overhead Conductors and Devices
676,638,392
28,088,318
574,730
704,151,980
54
(357) Underground Conduit
230,612,808
1,293,915
1,026
231,905,697
55
(358) Underground Conductors and Devices
565,592,514
1,497,762
600,331
563,494,421
56
(359) Roads and Trails
11,259,778
9,461,280
20,721,058
57
(359.1) Asset Retirement Costs for Transmission Plant
4,386,166
87,345
3,281,239
7,580,060
58
TOTAL Transmission Plant (Enter Total of lines 48 thru 57)
6,636,351,382
274,020,007
11,609,467
3,281,239
201,312
6,902,244,473
59
4. Distribution Plant
60
(360) Land and Land Rights
75,592,744
458,608
76,051,352
61
(361) Structures and Improvements
861,665,011
49,832,151
3,318,132
1,505,836
906,673,194
62
(362) Station Equipment
3,891,202,891
192,651,501
26,582,156
9,448,339
4,066,720,575
63
(363) Energy Storage Equipment – Distribution
639,173
364,469
274,704
64
(364) Poles, Towers, and Fixtures
2,781,652,581
271,039,419
25,071,173
3,027,620,827
65
(365) Overhead Conductors and Devices
4,178,819,538
446,219,108
96,906,283
4,528,132,363
66
(366) Underground Conduit
1,118,228,649
19,566,751
1,422,764
1,136,372,636
67
(367) Underground Conductors and Devices
7,725,708,874
522,088,455
48,687,814
8,199,109,515
68
(368) Line Transformers
1,576,826,539
98,754,637
37,654,126
8,143,785
1,629,783,265
69
(369) Services
1,445,845,133
33,780,802
4,431,730
1,475,194,205
70
(370) Meters
839,144,653
19,789,392
860,513
858,073,532
71
(371) Installations on Customer Premises
85,051,136
6,124,567
1,370,277
89,805,426
72
(372) Leased Property on Customer Premises
860,869
36,866
824,003
73
(373) Street Lighting and Signal Systems
209,840,585
7,295,907
6,938,283
210,198,209
74
(374) Asset Retirement Costs for Distribution Plant
45,151,168
229,774
11,009,611
33,911,783
75
TOTAL Distribution Plant (Enter Total of lines 60 thru 74)
24,836,229,544
1,666,741,355
253,473,025
11,009,611
257,326
26,238,745,589
76
5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77
(380) Land and Land Rights
78
(381) Structures and Improvements
79
(382) Computer Hardware
80
(383) Computer Software
81
(384) Communication Equipment
82
(385) Miscellaneous Regional Transmission and Market Operation Plant
83
(386) Asset Retirement Costs for Regional Transmission and Market Oper
84
TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85
6. General Plant
86
(389) Land and Land Rights
38,257,677
10
38,257,667
87
(390) Structures and Improvements
773,123,486
49,335,650
6,261,100
816,198,036
88
(391) Office Furniture and Equipment
162,851,779
29,218,220
23,507,768
168,562,231
89
(392) Transportation Equipment
453,114,856
39,625,876
10,773,501
481,967,231
90
(393) Stores Equipment
8,264,150
8,264,150
91
(394) Tools, Shop and Garage Equipment
270,646,440
12,317,809
179,348
282,784,901
92
(395) Laboratory Equipment
17,246,842
281,216
17,528,058
93
(396) Power Operated Equipment
7,865,504
124,530
7,740,974
94
(397) Communication Equipment
1,199,042,326
75,639,202
3,123,943
(c)
1,271,557,585
95
(398) Miscellaneous Equipment
19,396,592
4,311,879
23,708,471
96
SUBTOTAL (Enter Total of lines 86 thru 95)
2,949,809,652
210,605,312
43,845,660
3,116,569,304
97
(399) Other Tangible Property
98
(399.1) Asset Retirement Costs for General Plant
9,208,109
197,511
4,327,594
13,338,192
99
TOTAL General Plant (Enter Total of lines 96, 97, and 98)
2,959,017,761
210,605,312
44,043,171
4,327,594
3,129,907,496
100
TOTAL (Accounts 101 and 106)
35,539,268,984
2,255,356,767
348,187,156
3,400,778
458,638
37,443,496,455
101
(102) Electric Plant Purchased (See Instr. 8)
102
(Less) (102) Electric Plant Sold (See Instr. 8)
103
(103) Experimental Plant Unclassified
104
TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)
35,539,268,984
2,255,356,767
348,187,156
(a)
3,400,778
(b)
458,638
37,443,496,455


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: ElectricPlantInServiceAdjustments
The plant in-service adjustments of ($3,400,778) is the result of periodic reviews of, and changes to, the Company's asset retirement obligations.
(b) Concept: ElectricPlantInServiceTransfers
Represents net transfers from Account 105 (Plant Held for Future Use) of $458,638 and net transfers to Account 121 (Non-Utility Property) of $0.
(c) Concept: CommunicationEquipment
Of the balance reported in Account 397 (Communication Equipment) of $1,271,557,585 - 28.56% of such amount is directly assignable to the Transmission function.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No.
LesseeName
Name of Lessee
(a)
IndicationOfAssociatedCompany
* (Designation of Associated Company)
(b)
LeaseDescription
Description of Property Leased
(c)
CommissionAuthorization
Commission Authorization
(d)
ExpirationDateOfLease
Expiration Date of Lease
(e)
ElectricPlantLeasedToOthers
Balance at End of Year
(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
TOTAL


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
  1. Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use.
  2. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No.
ElectricPlantHeldForFutureUseDescription
Description and Location of Property
(a)
ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate
Date Originally Included in This Account
(b)
ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
Date Expected to be used in Utility Service
(c)
ElectricPlantHeldForFutureUse
Balance at End of Year
(d)
1 Land and Rights:
2
Transmission Plant (Land and/or Rights):
3
Charter Grove TSS
12/31/2006
(a)
01/01/2030
637,355
4
Cherry Valley-Silver Lake
06/30/1973
01/01/2035
1,827,050
5
Chicago-Northwestern R. R.
12/31/2001
01/01/2032
1,567,260
6
Eakin Creek TSS
09/30/1996
01/01/2035
2,670,479
7
Goodings Grove-Indiana Widening/Crete TSS
09/30/1971
01/01/2032
1,206,117
8
Manville-Pontiac
11/30/1972
01/01/2035
528,398
9
Plano-Charter Grove
06/30/1975
01/01/2035
4,343,302
10
Plato Center - 1
01/31/1992
01/01/2035
426,467
11
Sugar Grove-Blackberry
03/31/1991
01/01/2035
408,473
12
Waukegan Station 354kv Switchyard
12/31/2006
01/01/2035
799,826
13
Wayne-Itasca
12/31/1970
01/01/2035
4,099,384
14
Wilton Center-Joliet
05/31/1973
01/01/2035
352,474
15
Sugar Grove TSS
12/31/2012
01/01/2035
720,587
16
Sawyer TSS
12/31/2019
01/01/2030
441,267
17
18 items less than $250,000 each
1,166,115
18
19
20
21
22
23
24
25
26
27
21 Other Property:
22
Distribution Plant (Land and/or Rights):
23
Plato Center - 2
01/31/1992
01/01/2035
617,255
24
Rutland TDC
09/30/1996
01/01/2035
372,830
25
Lakeview - 1141 W. Diversey
12/01/2020
01/01/2029
11,729,191
26
Land - Aurora to Elgin-Kane
11/01/2021
01/01/2030
41,557,075
27
Plymouth Court
07/31/2022
01/01/2033
4,715,679
28
Jefferson GIS
12/31/2021
01/01/2028
7,718,755
29
29 items less than $250,000
1,428,482
30
General Plant (Land and\or RIghts)
31
1 items less than $250,000
8,281
47 TOTAL
89,342,102


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
The expected dates to be used in utility service are estimates and are subject to change.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
  1. Report below descriptions and balances at end of year of projects in process of construction (107).
  2. Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts).
  3. Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No.
ConstructionWorkInProgressProjectDescription
Description of Project
(a)
ConstructionWorkInProgress
Construction work in progress - Electric (Account 107)
(b)
1
Intangible Plant
2
Major projects:
3
ComEd/PECO CC&B Impl SW
205,258,941
4
EU GIS CORE SW
32,819,514
5
EU ADMS Implementation SW
29,270,235
6
ADMS SW
26,239,480
7
CEJA CC&B Integration CL CAP
13,914,592
8
ADMS - Cap Software #2 SW
12,034,576
9
Apollo Phase 2 W/O WPT SW
10,814,846
10
Outage Reporting and Analy -CL
8,228,449
11
ADMS RTU Testing SW
5,109,863
12
DER and Load Forecasting SW
3,608,293
13
ComEd IT Virtual FIG Retire SW
3,003,278
14
oneMDS Mobile Dispatch - SW
2,757,657
15
EU GIS DQ SW
2,739,882
16
oneMDS Mobile Dispatch SW RL4
2,532,230
17
PMU Analytics
2,361,418
18
uPPM - ADF SW
2,055,492
19
EU New Business Intellio CL
1,925,230
20
IGA Enhancement Program SW
1,851,081
21
ComEd/PECO CC&B Data Conv SW
1,735,856
22
GIS Transmission SW
1,364,539
23
Urbint (Energy Based) SW
1,149,636
24
CCB INST CONF CCB/MDM BX2 SW
1,079,386
25
Other Projects
(a)
14,715,653
26
Transmission Plant
27
RELO TSS101 Itasca 345kV - GIS
33,069,840
28
TSS 51 McCook 138kV Line
29,363,623
29
TSS 135 Elmhurst 345kV GIS
26,658,369
30
Upgrade 138kV Line 0108
11,193,701
31
TSS 135 Elmhurst Tran Hardn
10,968,550
32
TSS82 CROSBY SEC FENCING
9,641,491
33
CyrusOne Aurora TR at TSS111
4,398,052
34
UA HQ Data Center TSS184
3,805,216
35
TSS46 Des Plaines TR83 Rpl
3,783,621
36
OCC Static Switch Repair
3,498,144
37
INSTALL 3RD TR (40MVA) AT TDC2
3,289,416
38
TSS82 CROSBY SEC TECHNOLOGY
3,187,878
39
Chicago South Switchgear Repla
2,924,645
40
TSS78 Franklin Park L3705 PST
2,446,863
41
TSS 112 Wilton Center 345 kV 5
1,620,018
42
RELO TSS101 Itasca 345kV-Line
1,433,464
43
STA11 Fisk Cap Bank
1,395,105
44
L17105 Wood Pole Replacement
1,371,367
45
TSS112 Ridgeland - TR71 Matrl
1,218,082
46
TSS79 Spaulding TR76 Repl
1,133,998
47
Other Projects - 1
(b)
33,896,939
48
Distribution Plant
49
Major Projects:
50
Project Post TDC214 Expansion
34,170,869
51
5P210005-TSS79 34.5kV bus conf
22,546,371
52
PROJECT MIRACLE GROW
19,528,246
53
Project Post - ESS E 535 - 1
14,540,956
54
Cloud HQ Data Center-ESSE410
10,913,712
55
L17105 Wood Pole Replac
10,841,038
56
Project Post ESS
10,171,418
57
L19202 HPFF Replacement
9,379,986
58
8P230001 - TDC469 40MVA TR
8,926,835
59
Project Circle ESSE552
8,045,328
60
3P190201-Z11884
7,936,757
61
L1863/L1864/L1865 Relocation
7,060,725
62
L15625 Wood Pole Replacement
6,761,859
63
Indirects-Removal for Budget
6,613,244
64
TSS64 Bellwood 12kV Switchgear
6,021,434
65
TSS104 Ford City Intel Sub
5,699,557
66
Project Post - L21408
5,673,160
67
CULLINAN NEW FEEDER
5,481,543
68
Air Liquide New Feeder
5,476,087
69
L13349 Reconductor/Relocation
5,474,730
70
4P223700-DCE27 Arlington Hts’
5,197,105
71
78624 : Franklin Ave OH Reloca
5,094,974
72
TSS 82 Crosby Intel Sub
4,931,679
73
L7542 Customer Count
4,704,374
74
IP2 PCKT RELIABILITY-FDR H261
4,605,240
75
Retire 4kV Fdrs W405 W406 W438
4,525,266
76
Project Post - L21403
4,372,063
77
L19203 HPFF Replacement
4,024,477
78
1P240005-install 5th 50MVA TR
3,740,947
79
Aligned Data Cented 505 NW
3,645,767
80
34kV L13349 Rock Falls
3,191,517
81
BCM Controlled Generation
2,991,909
82
ESSG314 Christ Hospital
2,968,144
83
5P2302: new feeder D3429
2,945,146
84
Spare TR67MVA (3-Wind)Aligned
2,897,131
85
New Feeder Z17449
2,843,878
86
L13349- River Crossing INS CBL
2,834,590
87
McCook IL Joliet Rd
2,824,133
88
8P240200 RLV F5373
2,603,472
89
NORTHPOINT ELWOOD
2,552,518
90
1P190001-Install 5th TR
2,529,276
91
78784 : Canal btwn Madison & T
2,511,610
92
NTT Data Center Phase 2
2,504,733
93
CSX Midway Airport L5103 Reloc
2,503,214
94
SBA EDGE LINE EXTENSION
2,478,399
95
CTA Blue Line Harlem Relo
2,445,321
96
1050 W. Van Buren - Perm
2,366,580
97
4000 W Diversey Perm
2,344,842
98
3P211002-56TH144 12 KV CONV
2,337,340
99
6P230800 - 4:12 conversions
2,279,461
100
Bronzeville Microgrid PMU Inst
2,228,498
101
6001 S Stony Island Ave - OPC
2,213,826
102
CTA Damen Station Perm
2,128,281
103
1P230200: New Feeder Y3037
2,119,841
104
Project Circle NEW ESS
2,116,101
105
TDC556 Berwyn Improvmnt L19202
2,057,354
106
CTA Barry Station Perm
2,047,812
107
12 kV DA Program X4069
2,016,515
108
168 N ABERDEEN PERM
1,952,094
109
34kV Resiliency-L19342 Part 1
1,947,011
110
2021 F.A.U.L.T. Switch Install
1,903,379
111
1112 W CARROLL AVE - PERM
1,819,870
112
12 kV DA Baseline X1492
1,819,284
113
NTT Data Center ESS
1,783,705
114
TSS192 Rdglnd Improvmnt L19202
1,767,824
115
MR 2022 1300 GROUP NETCENTERS
1,682,570
116
110 N Wacker - Cable & Conduit
1,653,219
117
TSS 77 Mazon IP2 Brkr Replace
1,557,103
118
Perm Ser for 808 N. Cleveland
1,550,022
119
TDC785 Ontario PMU Deployment
1,548,527
120
TSS45 Replace TR73
1,529,334
121
IP^2 2021 IP2 - Z13783
1,516,310
122
1P250001-New Rockwell TDC
1,423,306
123
TSS192 Ridgeland TR71 Replcmnt
1,417,333
124
1131-1135 W Winona - Relo
1,416,904
125
2021 REACTS STA13_2 FOH
1,382,394
126
12 kV DA IP2 Y4540
1,379,266
127
2021 REACTS STA13 FOH
1,308,398
128
TSS114 Northwest PMU Deploymnt
1,285,763
129
DCY310 Austin TR1 Replacement
1,266,724
130
87495: NBSW-905,925,999 Belle
1,264,365
131
Christ Hosp Hardening L11567
1,261,694
132
GRIP 2016 12kV Y8256
1,237,023
133
12 kV DA X8442
1,235,869
134
South Elgin Security Technolog
1,229,800
135
Elgin Security Fence
1,210,882
136
28 E Garfield-Washington Park
1,161,132
137
DSS471 Pontiac BT 1-7
1,158,734
138
12 kV DA Baseline 319X246
1,154,279
139
210 N Aberdeen - Perm
1,149,863
140
79657 : IL-71 FROM 0.5MILE EAS
1,137,646
141
8P233700 4:12kV G53 & G56
1,118,812
142
Spare TR40MVA (2-Wind) Elwd P1
1,068,984
143
McHenry Security Technology
1,050,634
144
86790 : FOX LAKE IL59 & GRAND
1,044,866
145
Spare TR40MVA (2-Wind) Elwd P2
1,010,998
146
Spare TR 40MVA (2-Wind) Silv L
1,008,143
147
Other Projects - 2
(c)
207,893,021
148
General Plant
149
UPS A1/B1 Replacement
6,783,371
150
2020 REACTS STA18-TSS60 DFR
6,527,864
151
2019 REACTS TSS157-DCK15 BBF
6,236,563
152
Sugar Grove Trans Lines
6,139,660
153
NORTH VO TSS103 LISLE
6,014,654
154
REACTS 1C224302 TSS30-TSS30-03
5,428,572
155
Ucomm Fibers Svcs CED HW
4,527,898
156
REACTS Schmb E2016-W7415 DFR
4,237,005
157
Maywood Lab expansion
3,853,412
158
2020 REACTS TSS60-TSS60 7 DFR
3,578,377
159
2020 REACTS TSS193-TSS193 DFR
3,360,405
160
2021 REACTS DF-STA13-STA13-03
3,277,422
161
2021 REACTSDF-STA13_2STA13_2 1
3,208,818
162
2021 REACTS DF-STA13-STA13_2-1
3,141,264
163
Supply Automation Project
3,031,362
164
2021 REACTS DF-STA13-STA13-01
2,695,607
165
Long Term Performance Plan - 1
2,574,322
166
Long Term Performance Plan - 2
2,496,120
167
Long Term Performance Plan - 3
2,439,658
168
Long Term Performance Plan - 4
2,401,723
169
Long Term Performance Plan - 5
2,328,236
170
CHICAGO VO TSS150 CALUMET
2,323,780
171
Long Term Performance Plan - 6
2,289,454
172
REACTS R6511 DF TSS165 LINK 01
2,214,761
173
REACTS1C224303 TDC714-TDC714-2
2,197,533
174
DOE Energize
2,171,055
175
Libertyville Training Cntr Cap
2,164,670
176
Long Term Performance Plan - 7
2,154,675
177
Long Term Performance Plan - 8
2,145,482
178
REACTS 1C224303TDC714-TDC714-1
2,092,481
179
2020 REACTS TSS48-TSS48 DFR
2,060,918
180
2019 REACTS TSS945-TSS70 BBF
2,017,730
181
Siemens Controller BMG
2,007,378
182
WEST VO TSS75 CRYSTAL LAKE
1,793,265
183
Long Term Performance Plan - 9
1,709,513
184
2020 REACTS TDC447 to TSS73
1,670,719
185
2019 REACTS TDC294-TSS154 BBF
1,655,660
186
CHICAGO VO TSS54 Clybourn
1,585,865
187
ComEd/PECO CC&B Impl HW
1,555,469
188
Long Term Performance Plan - 10
1,529,203
189
CHICAGO VO STA13-3 Crawford
1,448,056
190
Chicago North EVCS 2023
1,444,853
191
Libertyville HQ HVAC Replcemnt
1,442,242
192
ADMS Task Force - HW
1,440,862
193
2020 REACnTS TDC206
1,413,368
194
REACTS AF-TSS139-TSS139-01.02
1,404,926
195
ATO Monitoring- Chicago
1,394,603
196
2020 REACTS BF-TSS137-SS895
1,390,707
197
2021 REACTS BF-TDC517-TDC531
1,348,357
198
REACTS1C224303 TDC714-TDC714-4
1,338,551
199
2020 REACTS LOC1-LOC2PA
1,286,763
200
2020 REACTS TSS73 to TSS179
1,278,962
201
2020 REACTS TSS60-TDC461-2 DFR
1,215,060
202
Libertyville Ceiling & Lightng
1,211,222
203
Long Term Performance Plan - 11
1,194,545
204
2021 REACTS BF-TSS118-SS875
1,183,012
205
2021 REACTS DF-STA13_2-TSS63-1
1,180,645
206
REACTS 1C224302 STA13-TSS30-01
1,164,160
207
2019 REACTS STA22-STA16 BBF
1,162,471
208
Private LTE Cores & Initia HW
1,135,892
209
2021 REACTS DF-STA13-STA13_2-2
1,055,257
210
Project Post - ESS E 535 - 2
1,042,119
211
2021 REACTS DF-STA13-STA13-07
1,014,858
212
Other Projects - 3
(d)
79,568,540
43
Total
1,395,544,738


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: ConstructionWorkInProgress
There are 54 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.
(b) Concept: ConstructionWorkInProgress
There are 294 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.
(c) Concept: ConstructionWorkInProgress
There are 2,147 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.
(d) Concept: ConstructionWorkInProgress
There are 588 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
  1. Explain in a footnote any important adjustments during year.
  2. Explain in a footnote any difference between the amount for book cost of plant retired, Line 12, column (c), and that reported for electric plant in service, page 204, column (d), excluding retirements of non-depreciable property.
  3. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications.
  4. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No.
Item
(a)
Total (c + d + e)
(b)
Electric Plant in Service
(c)
Electric Plant Held for Future Use
(d)
Electric Plant Leased To Others
(e)
Section A. Balances and Changes During Year
1
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance Beginning of Year
10,111,200,105
10,111,200,105
2
Depreciation Provisions for Year, Charged to
3
DepreciationExpenseExcludingAdjustments
(403) Depreciation Expense
1,006,052,806
1,006,052,806
4
DepreciationExpenseForAssetRetirementCosts
(403.1) Depreciation Expense for Asset Retirement Costs
1,858,923
1,858,923
5
ExpensesOfElectricPlantLeasedToOthers
(413) Exp. of Elec. Plt. Leas. to Others
6
TransportationExpensesClearing
Transportation Expenses-Clearing
28,804,787
28,804,787
7
OtherClearingAccounts
Other Clearing Accounts
8
OtherAccounts
Other Accounts (Specify, details in footnote):
9.1
Other Accounts (Specify, details in footnote):
3,796,054
(a)
3,796,054
10
DepreciationProvision
TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)
1,032,920,462
1,032,920,462
11
Net Charges for Plant Retired:
12
BookCostOfRetiredPlant
Book Cost of Plant Retired
303,544,568
(b)
303,544,568
13
CostOfRemovalOfPlant
Cost of Removal
187,215,953
187,215,953
14
SalvageValueOfRetiredPlant
Salvage (Credit)
9,757,100
9,757,100
15
NetChargesForRetiredPlant
TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)
481,003,421
481,003,421
16
OtherAdjustmentsToAccumulatedDepreciation
Other Debit or Cr. Items (Describe, details in footnote):
17.1
Other Debit or Cr. Items (Describe, details in footnote):
739,404
(c)
739,404
18
BookCostOfAssetRetirementCosts
Book Cost or Asset Retirement Costs Retired
514,630
514,630
19
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)
10,663,341,920
10,663,341,920
Section B. Balances at End of Year According to Functional Classification
20
AccumulatedDepreciationSteamProduction
Steam Production
21
AccumulatedDepreciationNuclearProduction
Nuclear Production
22
AccumulatedDepreciationHydraulicProductionConventional
Hydraulic Production-Conventional
23
AccumulatedDepreciationHydraulicProductionPumpedStorage
Hydraulic Production-Pumped Storage
24
AccumulatedDepreciationOtherProduction
Other Production
25
AccumulatedDepreciationTransmission
Transmission
1,737,175,257
1,737,175,257
26
AccumulatedDepreciationDistribution
Distribution
7,530,867,345
7,530,867,345
27
AccumulatedDepreciationRegionalTransmissionAndMarketOperation
Regional Transmission and Market Operation
28
AccumulatedDepreciationGeneral
General
1,395,299,318
(d)
1,395,299,318
29
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
TOTAL (Enter Total of lines 20 thru 28)
10,663,341,920
10,663,341,920


FOOTNOTE DATA

(a) Concept: OtherAccounts
Accumulated Depreciation on asset retirement costs charged primarily to Account 182.3 $ (3,796,054)
(b) Concept: BookCostOfRetiredPlant
Retirements per Page 219 for Account 108 $ 303,544,568 
Retirements per Page 204 for Plant in Service 348,187,154 
Difference $ 44,642,586 
Details of Difference:
Retirement of Asset Retirement Costs for FIN 47 $ 514,630 
Retirement of Leasehold improvements charged to Account 111 - Accumulated Provisions for Amortization 5,066,464 
Retirement of Software charged to Account 111 39,061,492 
Total $ 44,642,586 
(c) Concept: OtherAdjustmentsToAccumulatedDepreciation
Adjustments to Account 108 - Accumulated Provision for Depreciation - for revisions recorded to the Asset Retirement Obligations and ARO Regulatory Assets $ 756,864 
Adjustments to Account 108 - Accumulated Provision for Depreciation - for transfers related to the refunctionalization of assets and miscellaneous expense adjustments (17,460)
Total $ 739,404 
(d) Concept: AccumulatedDepreciationGeneral
The amount of accumulated depreciation associated with Account 397 (Communication Equipment) as of December 31, 2023 is $862,664,375.07 - 28.56% of such amount is directly assignable to the Transmission function, and 71.44% of such amount is directly assignable to the Distribution function

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
  1. Report below investments in Account 123.1, Investments in Subsidiary Companies.
  2. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal.
  3. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1.
  4. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge.
  5. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number.
  6. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year.
  7. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f).
  8. Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No.
DescriptionOfInvestmentsInSubsidiaryCompanies
Description of Investment
(a)
DateOfAcquisitionInvestmentsInSubsidiaryCompanies
Date Acquired
(b)
DateOfMaturityInvestmentsInSubsidiaryCompanies
Date of Maturity
(c)
InvestmentInSubsidiaryCompanies
Amount of Investment at Beginning of Year
(d)
EquityInEarningsOfSubsidiaryCompanies
Equity in Subsidiary Earnings of Year
(e)
InterestAndDividendRevenueFromInvestments
Revenues for Year
(f)
InvestmentInSubsidiaryCompanies
Amount of Investment at End of Year
(g)
InvestmentGainLossOnDisplosal
Gain or Loss from Investment Disposed of
(h)
1
Commonwealth Edison Company of Indiana, Inc.
12/31/1962
2
Common Stock, no par value (III. C.C. Docket Number 46967)
6,189,528
6,189,528
3
Other Capital Stock Transactions - Net
34,161,813
34,161,813
4
Undistributed Earnings
50,194,838
5,124,608
356,735
55,676,181
5
Subtotal
90,546,179
5,124,608
356,735
96,027,522
6
ComEd Financing III
7
Common Securities (III. C. C. Docket Number 02-0562)
6,186,000
6,186,000
8
Undistributed Earnings
115,661
392,811
392,811
115,661
9
Subtotal
6,301,661
392,811
392,811
6,301,661
10
EdiSun, LLC
11
Ownership Interest
61,592
61,592
12
RITELine Illinois, LLC
13
Ownership Interest
20,537
20,537
42
Total Cost of Account 123.1 $
12,375,528
Total
96,806,785
5,517,419
36,076
102,288,128


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
MATERIALS AND SUPPLIES
  1. For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material.
  2. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No.
Account
(a)
Balance Beginning of Year
(b)
Balance End of Year
(c)
Department or Departments which Use Material
(d)
1
Fuel Stock (Account 151)
2
Fuel Stock Expenses Undistributed (Account 152)
3
Residuals and Extracted Products (Account 153)
4
Plant Materials and Operating Supplies (Account 154)
5
Assigned to - Construction (Estimated)
180,001,069
(a)
268,199,577
6
Assigned to - Operations and Maintenance
7
Production Plant (Estimated)
8
Transmission Plant (Estimated)
6,123,521
4,642,775
Transmission
9
Distribution Plant (Estimated)
8,890,161
12,718,935
Distribution
10
Regional Transmission and Market Operation Plant (Estimated)
11
Assigned to - Other (provide details in footnote)
12
TOTAL Account 154 (Enter Total of lines 5 thru 11)
195,014,751
285,561,287
13
Merchandise (Account 155)
14
Other Materials and Supplies (Account 156)
15
Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)
16
Stores Expense Undistributed (Account 163)
17
18
19
20
TOTAL Materials and Supplies
195,014,751
285,561,287


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesConstruction
Assigned to - Construction (Estimated)
Transmission Plant (Estimated) $ 57,496,141 
Distribution Plant (Estimated) 210,703,436 
Assigned to - Construction (Estimated) $ 268,199,577 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
Allowances (Accounts 158.1 and 158.2)
  1. Report below the particulars (details) called for concerning allowances.
  2. Report all acquisitions of allowances at cost.
  3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts.
  4. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k).
  5. Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.
  6. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances.
  7. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts).
  8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies.
  9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
  10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
Current Year Year One Year Two Year Three Future Years Totals
Line No.
SO2 Allowances Inventory (Account 158.1)
(a)
No.
(b)
Amt.
(c)
No.
(d)
Amt.
(e)
No.
(f)
Amt.
(g)
No.
(h)
Amt.
(i)
No.
(j)
Amt.
(k)
No.
(l)
Amt.
(m)
1
Balance-Beginning of Year
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
5
Returned by EPA
6
7
8
9
10
11
12
13
14
15
Total
16
17
Relinquished During Year:
18
Charges to Account 509
19
Other:
20
Allowances Used
20.1
Allowances Used
21
Cost of Sales/Transfers:
22
23
24
25
26
27
28
Total
29
Balance-End of Year
30
31
Sales:
32
Net Sales Proceeds(Assoc. Co.)
33
Net Sales Proceeds (Other)
34
Gains
35
Losses
Allowances Withheld (Acct 158.2)
36
Balance-Beginning of Year
37
Add: Withheld by EPA
38
Deduct: Returned by EPA
39
Cost of Sales
40
Balance-End of Year
41
42
Sales
43
Net Sales Proceeds (Assoc. Co.)
44
Net Sales Proceeds (Other)
45
Gains
46
Losses


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
Allowances (Accounts 158.1 and 158.2)
  1. Report below the particulars (details) called for concerning allowances.
  2. Report all acquisitions of allowances at cost.
  3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts.
  4. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k).
  5. Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.
  6. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances.
  7. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts).
  8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies.
  9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
  10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
Current Year Year One Year Two Year Three Future Years Totals
Line No.
NOx Allowances Inventory (Account 158.1)
(a)
No.
(b)
Amt.
(c)
No.
(d)
Amt.
(e)
No.
(f)
Amt.
(g)
No.
(h)
Amt.
(i)
No.
(j)
Amt.
(k)
No.
(l)
Amt.
(m)
1
Balance-Beginning of Year
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
5
Returned by EPA
6
7
8
9
10
11
12
13
14
15
Total
16
17
Relinquished During Year:
18
Charges to Account 509
19
Other:
20
Allowances Used
20.1
Allowances Used
21
Cost of Sales/Transfers:
22
23
24
25
26
27
28
Total
29
Balance-End of Year
30
31
Sales:
32
Net Sales Proceeds(Assoc. Co.)
33
Net Sales Proceeds (Other)
34
Gains
35
Losses
Allowances Withheld (Acct 158.2)
36
Balance-Beginning of Year
37
Add: Withheld by EPA
38
Deduct: Returned by EPA
39
Cost of Sales
40
Balance-End of Year
41
42
Sales
43
Net Sales Proceeds (Assoc. Co.)
44
Net Sales Proceeds (Other)
45
Gains
46
Losses


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
WRITTEN OFF DURING YEAR
Line No.
DescriptionOfExtraordinaryPropertyLoss
Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).]
(a)
ExtraordinaryPropertyLossesNotYetRecognized
Total Amount of Loss
(b)
ExtraordinaryPropertyLossesRecognized
Losses Recognized During Year
(c)
ExtraordinaryPropertyLossesWrittenOffAccountCharged
Account Charged
(d)
ExtraordinaryPropertyLossesWrittenOff
Amount
(e)
ExtraordinaryPropertyLosses
Balance at End of Year
(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
20 TOTAL


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
WRITTEN OFF DURING YEAR
Line No.
DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts
Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)]
(a)
UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized
Total Amount of Charges
(b)
UnrecoveredPlantAndRegulatoryStudyCostsRecognized
Costs Recognized During Year
(c)
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged
Account Charged
(d)
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff
Amount
(e)
UnrecoveredPlantAndRegulatoryStudyCosts
Balance at End of Year
(f)
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
TOTAL


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
Transmission Service and Generation Interconnection Study Costs
  1. Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies.
  2. List each study separately.
  3. In column (a) provide the name of the study.
  4. In column (b) report the cost incurred to perform the study at the end of period.
  5. In column (c) report the account charged with the cost of the study.
  6. In column (d) report the amounts received for reimbursement of the study costs at end of period.
  7. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.
DescriptionOfStudyPerformed
Description
(a)
StudyCostsIncurred
Costs Incurred During Period
(b)
StudyCostsAccountCharged
Account Charged
(c)
StudyCostsReimbursements
Reimbursements Received During the Period
(d)
StudyCostsAccountReimbursed
Account Credited With Reimbursement
(e)
1
Transmission Studies
2
PJM AD1-031 Kewanee-ED Edwards
31
751
3
PJM AD1-031 Kewanee-ED Edwards
91
4
PJM AD1-031 Kewanee-ED Edwards
423
5
PJM AD1-031 Kewanee-ED Edwards
206
6
PJM AD2-047 Davis Creek 138kV
126
1,846
7
PJM AD2-047 Davis Creek 138kV
370
8
PJM AD2-047 Davis Creek 138kV
1,630
9
PJM AD2-047 Davis Creek 138kV
359
10
PJM AD2-066 Mazon-Crescent Rid
32
539
11
PJM AD2-066 Mazon-Crescent Rid
102
12
PJM AD2-066 Mazon-Crescent Rid
733
13
PJM AD2-066 Mazon-Crescent Rid
20
14
PJM AD2-066 Mazon-Crescent Rid
80
15
PJM AE1-070 Elwood 345 kV Faci
103
2,923
16
PJM AE1-070 Elwood 345 kV Faci
299
17
PJM AE1-070 Elwood 345 kV Faci
1,804
18
PJM AE1-070 Elwood 345 kV Faci
717
19
Powerton-Nevada FS AE1-163
244
19,325
20
Powerton-Nevada FS AE1-163
848
21
Powerton-Nevada FS AE1-163
15,473
22
Powerton-Nevada FS AE1-163
2,760
23
AE1-193 PJM Facilities Study-K
134
3,855
24
AE1-193 PJM Facilities Study-K
394
25
AE1-193 PJM Facilities Study-K
2,379
26
AE1-193 PJM Facilities Study-K
948
27
AE1-194 PJM Facilities Study-K
92
2,853
28
AE1-194 PJM Facilities Study-K
274
29
AE1-194 PJM Facilities Study-K
1,817
30
AE1-194 PJM Facilities Study-K
670
31
AE1-195 PJM Facilities Study
92
2,853
32
AE1-195 PJM Facilities Study
274
33
AE1-195 PJM Facilities Study
1,817
34
AE1-195 PJM Facilities Study
670
35
AE1-198 PJM Facilities Study
372
20
Total
34,134
33,867
21
Generation Studies
22
Twombly Facility Study
927
1,004
23
Twombly Facility Study
77
24
PJM AD1-039 Kendall-Tazewell
10
272
25
PJM AD1-039 Kendall-Tazewell
163
26
PJM AD1-039 Kendall-Tazewell
30
27
PJM AD1-039 Kendall-Tazewell
69
28
AD1-098 Dixon to McFirr PJM
1,889
98,384
29
AD1-098 Dixon to McFirr PJM
73,610
30
AD1-098 Dixon to McFirr PJM
5,868
31
AD1-098 Dixon to McFirr PJM
17,017
32
100 Facility Study
23
620
33
100 Facility Study
371
34
100 Facility Study
68
35
100 Facility Study
158
36
102 Facility Study
27
702
37
102 Facility Study
422
38
102 Facility Study
75
39
102 Facility Study
178
40
Shady Oaks Facility Study
683
45,365
41
Shady Oaks Facility Study
35,251
42
Shady Oaks Facility Study
2,164
43
Shady Oaks Facility Study
7,267
44
Rock Falls Garden Facility Study
4
92
45
Rock Falls Garden Facility Study
52
46
Rock Falls Garden Facility Study
11
47
Rock Falls Garden Facility Study
25
48
AE1-114 PJM Facilities Study
522
13,069
49
AE1-114 PJM Facilities Study
7,784
50
AE1-114 PJM Facilities Study
1,392
51
AE1-114 PJM Facilities Study
3,371
52
AE1-166 PJM Facilities Study
235
7,629
53
AE1-166 PJM Facilities Study
4,918
54
AE1-166 PJM Facilities Study
699
55
AE1-166 PJM Facilities Study
1,777
56
AE1-205 PJM Facilities Study
346
12,006
57
AE1-205 PJM Facilities Study
7,919
58
AE1-205 PJM Facilities Study
1,048
59
AE1-205 PJM Facilities Study
2,693
60
AE1-252 PJM Facilities Study
93
2,857
61
AE1-252 PJM Facilities Study
1,819
62
AE1-252 PJM Facilities Study
274
63
AE1-252 PJM Facilities Study
671
64
PJM AE2-152 Loretto-WiltonBrai
485
22,107
65
PJM AE2-152 Loretto-WiltonBrai
17,789
66
PJM AE2-152 Loretto-WiltonBrai
781
67
PJM AE2-152 Loretto-WiltonBrai
661
68
PJM AE2-152 Loretto-WiltonBrai
3,087
69
PJM AE2-173: MCLEAN 345 KV
1,415
59,343
70
PJM AE2-173: MCLEAN 345 KV
42,600
71
PJM AE2-173: MCLEAN 345 KV
3,901
72
PJM AE2-173: MCLEAN 345 KV
11,427
73
PJM AE2-341 Facility Study
87
8,566
74
PJM AE2-341 Facility Study
7,081
75
PJM AE2-341 Facility Study
257
76
PJM AE2-341 Facility Study
1,141
77
Nelson Facility Study - Elec Junction
26
2,197
78
Nelson Facility Study - Elec Junction
1,812
79
Nelson Facility Study - Elec Junction
72
80
Nelson Facility Study - Elec Junction
287
81
PJM AF1-030 Facility Study
150
8,375
82
PJM AF1-030 Facility Study
6,293
83
PJM AF1-030 Facility Study
483
84
PJM AF1-030 Facility Study
1,449
85
AF-2041 Nelson-Elec Junc 345kV
10
286
86
AF-2041 Nelson-Elec Junc 345kV
182
87
AF-2041 Nelson-Elec Junc 345kV
27
88
AF-2041 Nelson-Elec Junc 345kV
67
89
PJM AFS-128 Crescent Ridge-Cor
72
4,066
90
PJM AFS-128 Crescent Ridge-Cor
3,129
91
PJM AFS-128 Crescent Ridge-Cor
209
92
PJM AFS-128 Crescent Ridge-Cor
656
93
AF2-199 Nelson-Elec Junc 345kV
9
285
94
AF2-199 Nelson-Elec Junc 345kV
182
95
AF2-199 Nelson-Elec Junc 345kV
27
96
AF2-199 Nelson-Elec Junc 345kV
67
97
AF2-349 Garden Prairie 345 kV
150
15,117
98
AF2-349 Garden Prairie 345 kV
11,874
99
AF2-349 Garden Prairie 345 kV
1,003
100
AF2-349 Garden Prairie 345 kV
2,218
101
PJM TFAJ1464
613
40,523
102
PJM TFAJ1464
31,589
103
PJM TFAJ1464
2,015
104
PJM TFAJ1464
6,306
105
Mole Creek Facility Study
89
7,897
106
Mole Creek Facility Study
6,370
107
Mole Creek Facility Study
302
108
Mole Creek Facility Study
1,136
109
UPRATE AD2-194 @TSS 929
944
42,581
110
UPRATE AD2-194 @TSS 929
31,532
111
UPRATE AD2-194 @TSS 929
2,316
112
UPRATE AD2-194 @TSS 929
7,789
113
JM MISO J955 FACILITIES STUDY
2,532
85,260
114
JM MISO J955 FACILITIES STUDY
61,048
115
JM MISO J955 FACILITIES STUDY
5,191
116
JM MISO J955 FACILITIES STUDY
16,489
117
ISO J1377 - PJM Facilities
339
6,383
118
ISO J1377 - PJM Facilities
3,808
119
ISO J1377 - PJM Facilities
675
120
ISO J1377 - PJM Facilities
1,561
121
AC1-171 Expense
1
122
Normandy-Kewanee 138kV U4-027
158
39
Total
484,386
483,719
40 Grand Total
518,520
517,586


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
OTHER REGULATORY ASSETS (Account 182.3)
  1. Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable.
  2. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes.
  3. For Regulatory Assets being amortized, show period of amortization.
CREDITS
Line No.
DescriptionAndPurposeOfOtherRegulatoryAssets
Description and Purpose of Other Regulatory Assets
(a)
OtherRegulatoryAssets
Balance at Beginning of Current Quarter/Year
(b)
IncreaseDecreaseInOtherRegulatoryAssets
Debits
(c)
OtherRegulatoryAssetsWrittenOffAccountCharged
Written off During Quarter/Year Account Charged
(d)
OtherRegulatoryAssetsWrittenOffRecovered
Written off During the Period Amount
(e)
OtherRegulatoryAssets
Balance at end of Current Quarter/Year
(f)
1
(a)
Capitalized Employee Incentive Payments
5,384,614
287,485
5,097,129
2
Deferred Asset Retirement Obligation Costs
98,582,971
7,608,909
1,725,375
104,466,505
3
Cash Flow Swap Settlement Costs
5,238,366
519,507
4,718,859
4
MGP Remediation Costs
293,207,717
35,238,367
42,238,955
286,207,129
5
Renewable Energy Swaps
84,619,628
49,013,174
133,632,802
6
AMI Meter Accelerated Depreciation
47,654,975
19,582,450
28,072,525
7
Carbon Mitigation Credit
843,029,431
679,334,695
849,821,106
672,543,020
8
Rate Case
2,160,188
5,128,081
2,067,098
5,221,171
9
Uncollectible Accounts Expense - Under Recovery
46,912,297
40,664,866
9,122,925
78,454,238
10
Distribution Service Costs
406,058,390
531,266,870
50,743,686
886,581,574
11
Energy Efficiency Costs
1,433,937,303
453,019,091
195,519,578
1,691,436,816
12
Capital Lease Excess Depreciation
1,658,561
151,224
1,809,785
13
Purchased Receivables Program - Under Recovery
10,726,591
3,650,253
14,376,844
14
Purchased Electricity - Under Recovery
37,823,561
26,492,153
48,903,388
15,412,326
15
Distributed Generation Rebate Costs
98,485,989
19,211,025
9,264,200
108,432,814
16
Transmission Costs - Under Recovery
8,448,386
6,355,892
14,804,278
17
Parallel Operation of Retail Customer Generating Facilities Community Supply
358,059
5,711,099
3,196,304
2,872,854
18
Coal to Solar
19
Zero Emissions Program
59,681,968
1,570,047
58,111,921
20
Deferred Income Taxes
284,311,635
284,311,635
44
TOTAL
3,424,287,027
2,206,839,302
1,234,562,104
4,396,564,225


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
Line Item Rate Order Docket Number Or Recovery Mechanism Amortization Period
Capitalized Employee Incentive Payments ICC Docket 01-0423 3/31/2003 - 7/31/2043
Deferred Asset Retirement Obligation Costs Distribution & Transmission Formula Rates Over the life of related Assets
Cash Flow Swap Settlement Costs Distribution & Transmission Formula Rates 3/15/2002 - 1/31/2033
MGP Remediation Costs ICC Docket 05-0597 1/1/2007 - 12/31/2025
Renewable Energy Swaps ICC Docket No. 09-0373 6/1/2012 - 5/1/2032
AMI Meter Accelerated Depreciation ICC Docket 12-0298 1/1/2014-12/31/2028
Carbon Mitigation Credit CEJA BA: 12 months from June 2023

and

MR: 4 months from period end
Rate Case CEJA 1/1/2024-12/31/2027
Uncollectible Accounts Expense ICC Docket No. 09-0433 & 20-0309 12 months from each June
Distribution Service Costs EIMA & FEJA
SB2408 - Clean Energy Law - Distribution Formula Transition for year 2022 & 2023
3-5 years
Energy Efficiency Costs FEJA Over the measurable life of efficiency measures
Capital Lease Excess Depreciation Distribution Formula Rate 2039 - 2053
Purchased Receivables Program - Under Recovery ICC Docket 10-0138 1/1/2011 - 12/31/2020
Purchased Electricity - Under Recovery ICC Docket No. 05-0159 & 18-1824 4 months from period end
Distributed Generation Rebate Costs FEJA 15 years
Transmission Costs - Under Recovery FERC Docket ER07-583 12 months from each June
Parallel Operation of Retail Customer Generating Facilities Community Supply ICC Docket 22-0305 Not determined yet
Zero Emissions Program FEJA 9 months from each September
Deferred Income Taxes ICC Order 18-0034 / FERC Order ER19-5 dated 4/26/19 Over the life of related assets

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
MISCELLANEOUS DEFFERED DEBITS (Account 186)
  1. Report below the particulars (details) called for concerning miscellaneous deferred debits.
  2. For any deferred debit being amortized, show period of amortization in column (a)
  3. Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
CREDITS
Line No.
Description of Miscellaneous Deferred Debits
(a)
Balance at Beginning of Year
(b)
Debits
(c)
Credits Account Charged
(d)
Credits Amount
(e)
Balance at End of Year
(f)
1
Accumulated under/Over recoveries -local government
2
compliance causes
280,674
1,851,431
1,733,985
398,120
3
Vacation pay and payroll taxes pending proper accounting
4
distribution
24,302,455
335,087,631
333,607,546
25,782,540
5
Long-Term contracting services
604,063
40,529
355,920
288,672
6
Cook County Forest Preserve District License Fees to be
7
amortized through 2027 - 1
3,860,550
4,974,786
5,492,975
3,342,361
8
Pension Asset
1,206,194,555
23,812,127
12,825,430
1,217,181,252
9
Long Term receivable from Constellation Energy Generation, LLC (formerly Exelon Generation Company, LLC) (SFAS 143, Regulatory Liability offset)
2,659,759,104
668,146,758
373,493,682
2,954,412,180
10
Long Term receivable from the MBA Plan
2,131,997
65,023,044
64,420,543
2,734,498
11
Credit facilities - ICC fees and other issuance costs to be
12
amortized through 2027 - 2
962,105
658,507
303,598
13
ICC Financing Authority Fees
3,221,803
4,800,000
2,340,000
5,681,803
14
Insurance recoveries related to third party claims
6,272,776
1,983,070
1,025,000
7,230,846
15
Estimated Illinois Distribution Tax Refund
6,567,897
4,660,257
7,166,937
4,061,217
16
Long Term Restricted Cash
116,893,579
133,291,678
76,637,041
173,548,216
17
Long-Term Receivable Related to the FERC 494 Refund
10,557,277
5,278,637
5,278,640
18
Microgrid Prepayment
446,414
82,175
364,239
19
Adjustable Block REC Prepayments
367,819,028
211,674,764
4,219,914
575,273,878
20
Long-term portion of receivables from deferred payment
21
agreements
1,381,006
432,275
423,536
1,389,745
22
Rochelle Franchise Fees to be amortized through 2070
1,410,000
30,000
1,380,000
23
Illinois Solar for All Program REC Prepayment
7,359,346
7,998,673
391,237
14,966,782
24
Meter/Equipment Purchases
33,415
2,222
35,637
25
REACTS Fiber Program
182,942
43,605
139,337
26
Skydio Cloud 3yr Subscription Purchase
187,425
93,713
93,712
27
I&M Canal Fees to be amortized through June 2033
446,967
16,867
430,100
28
Maywood Outdoor Lab Program
816,074
816,074
29
Minor Items
2,652,752
466,287,275
466,798,817
2,141,210
47
Miscellaneous Work in Progress
249,008
228,940
48
Deferred Regulatory Comm. Expenses (See pages 350 - 351)
49
TOTAL
4,423,330,171
4,997,467,960


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged
Accumulated under/over recoveries are offset in Accounts 107000, 108030, 535250, 615000, 143300,410090, 131000, 232100, and 503000.
(b) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged
Minor items are offset in Accounts 107000, 131100, 182890, 184100, 184200, 228200, 232000, 232900, 241000, 242000, 242200, 242300, 514000, 514062, 517010, 535000 and 535160.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
ACCUMULATED DEFERRED INCOME TAXES (Account 190)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes.
  2. At Other (Specify), include deferrals relating to other income and deductions.
Line No.
DescriptionOfAccumulatedDeferredIncomeTax
Description and Location
(a)
AccumulatedDeferredIncomeTaxes
Balance at Beginning of Year
(b)
AccumulatedDeferredIncomeTaxes
Balance at End of Year
(c)
1
Electric
2
(a)
268,238,892
1,006,863,343
7
Other
8
TOTAL Electric (Enter Total of lines 2 thru 7)
268,238,892
(b)
1,006,863,343
9
Gas
15
Other
16
TOTAL Gas (Enter Total of lines 10 thru 15)
17.1
Other (Specify)
17
Other (Specify)
18
TOTAL (Acct 190) (Total of lines 8, 16 and 17)
268,238,892
1,006,863,343
Notes


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxes
Account 190 Federal Inc. Activity:
410 Debits $ 52,429,002 
411 Credits 177,730,923 
Net Debit/(Credits) $ (125,301,921)
Account 190 State Inc. Activity:
410 Debits $ 538,996 
411 Credits 14,301,851 
Net Debit/(Credits) $ (13,762,855)
Account 190 Activity B/S Only:
Debits $ 599,559,675 
Credits — 
Net Adjustments $ 599,559,675 
Net Change $ 738,624,451 
(b) Concept: AccumulatedDeferredIncomeTaxes
Account 190 Description:
Accrued Benefits $ 2,455,092  $ 4,018,069 
Accrued Bonuses & Incentives 38,115,349  43,529,546 
Accrued Legal 14,226  14,253 
Accrued Severance 780,354  1,019,238 
Accrued Vacation 9,904,991  10,314,195 
Accrued Workers' Compensation 17,692,874  22,654,211 
Accrued OPEB 52,482,346  47,474,964 
Allowance for Doubtful Accounts 23,718,257  23,640,736 
Charitable Contribution Carryforward 1,975,093  — 
Corporate Alternative Minimum Tax —  118,023,568 
Deferred Compensation 8,250,079  8,499,188 
Deferred Revenue 2,868,752  2,405,758 
Environmental Cleanup Costs 431,243  13,150,719 
Manufactured Gas Plants 127,777,860  73,091,938 
Obsolete Materials 2,250,259  1,809,907 
Other - 190 22,051,220  9,892,629 
Regulatory Liability (11,510,534) 620,745,033 
State Income Taxes 7,221,187  4,294,062 
Unamortized Investment Tax Credit (38,239,756) 2,285,329 
Total $ 268,238,892  $ 1,006,863,343 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
CAPITAL STOCKS (Account 201 and 204)
  1. Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible.
  2. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year.
  3. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued.
  4. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative.
  5. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year.
  6. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No.
Class and Series of Stock and Name of Stock Series
(a)
Number of Shares Authorized by Charter
(b)
Par or Stated Value per Share
(c)
Call Price at End of Year
(d)
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares
(e)
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount
(f)
Held by Respondent As Reacquired Stock (Acct 217) Shares
(g)
Held by Respondent As Reacquired Stock (Acct 217) Cost
(h)
Held by Respondent In Sinking and Other Funds Shares
(i)
Held by Respondent In Sinking and Other Funds Amount
(j)
1
Common Stock (Account 201)
2
(a)
Total Common Stock
250,000,000
127,021,399
1,587,297,032
6
Total
250,000,000
127,021,399
1,587,297,032
7
Preferred Stock (Account 204)
8
9
10
11
Total
1
Capital Stock (Accounts 201 and 204) - Data Conversion
2
3
4
5
Total


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: CapitalStockDescription
ComEd had 60,032 and 60,051 warrants outstanding to purchase ComEd common stock at December 31, 2023 and 2022, respectively. The warrants entitle the holders to convert such warrants into common stock of ComEd at a conversion rate of one share of common stock for three warrants. At December 31, 2023 and 2022, 20,011 and 20,017 shares of common stock, respectively, were reserved for the conversion of warrants.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2023-12-31
Year/Period of Report

End of:
2023
/
Q4
Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change.
  1. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation.
  2. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related.
  3. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related.
  4. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No.
Item
(a)
Amount
(b)
1
DonationsReceivedFromStockholdersAbstract
Donations Received from Stockholders (Account 208)
2
DonationsReceivedFromStockholders
Beginning Balance Amount
3.1
IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders
Increases (Decreases) from Sales of Donations Received from Stockholders
4
DonationsReceivedFromStockholders
Ending Balance Amount
5
ReductionInParOrStatedValueOfCapitalStockAbstract
Reduction in Par or Stated Value of Capital Stock (Account 209)
6
ReductionInParOrStatedValueOfCapitalStock
Beginning Balance Amount
7.1
IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock
Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8
ReductionInParOrStatedValueOfCapitalStock
Ending Balance Amount
9
GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract
Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10
GainOnResaleOrCancellationOfReacquiredCapitalStock
Beginning Balance Amount
11.1
IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock
Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock
12
GainOnResaleOrCancellationOfReacquiredCapitalStock
Ending Balance Amount
13
MiscellaneousPaidInCapitalAbstract
Miscellaneous Paid-In Capital (Account 211)
14
MiscellaneousPaidInCapital
Beginning Balance Amount
4,733,210,990
15.1
IncreasesDecreasesDueToMiscellaneousPaidInCapital
Increases (Decreases) Due to Warrants
(a)
253
15.2
IncreasesDecreasesDueToMiscellaneousPaidInCapital
Increases (Decreases) Due to Miscellaneous Paid-In Capital
655,545,330
16
MiscellaneousPaidInCapital
Ending Balance Amount
(b)
5,388,756,067
17
OtherPaidInCapitalAbstract
Historical Data - Other Paid in Capital
18
OtherPaidInCapitalDetail
Beginning Balance Amount
19.1
IncreasesDecreasesInOtherPaidInCapital
Increases (Decreases) in Other Paid-In Capital
20
OtherPaidInCapitalDetail
Ending Balance Amount
40
OtherPaidInCapital
Total
5,388,756,067


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2023-12-31
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: IncreasesDecreasesDueToMiscellaneousPaidInCapital
These amounts represent the balances related to the following types of Common Stock Purchase Warrants:
Beginning Balance as of 12/31/2022 2023 YTD Activity Ending Balance as of 12/31/2023
1971 Warrants 526,006  (195) 525,811 
Series B Warrants 227,208  (58) 227,150 
Total Warrants 753,214   (253) 752,961  
(b) Concept: MiscellaneousPaidInCapital
The ending balance is comprised of $752,961 for Common Stock Purchase Warrants and $5,388,003,106 of other paid in capital. This other paid in capital amount represents the other paid in capital recognized from the indemnification from Exelon Corporation, the Respondent's parent, in related to the like-kind exchange transaction and to support expanded capital programs. See Note 7 - Income Taxes of the Notes to Financial Statements for additional information related to the like-kind exchanges.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
CAPITAL STOCK EXPENSE (Account 214)
  1. Report the balance at end of the year of discount on capital stock for each class and series of capital stock.
  2. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No.
NameOfClassAndSeriesOfStock
Class and Series of Stock
(a)
CapitalStockExpense
Balance at End of Year
(b)
1
Common Stock
6,942,925
22
TOTAL
6,942,925


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
LONG-TERM DEBT (Account 221, 222, 223 and 224)
  1. Report by Balance Sheet Account the details concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt.
  2. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds, and in column (b) include the related account number.
  3. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received, and in column (b) include the related account number.
  4. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued, and in column (b) include the related account number.
  5. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates.
  6. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge.
  7. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote.
  8. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (m). Explain in a footnote any difference between the total of column (m) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies.
  9. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No.
ClassAndSeriesOfObligationCouponRateDescription
Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates)
(a)
RelatedAccountNumber
Related Account Number
(b)
Principal Amount of Debt Issued
(c)
LongTermDebtIssuanceExpensePremiumOrDiscount
Total Expense, Premium or Discount
(d)
LongTermDebtIssuanceExpenses
Total Expense
(e)
LongTermDebtPremium
Total Premium
(f)
LongTermDebtDiscount
Total Discount
(g)
NominalDateOfIssue
Nominal Date of Issue
(h)
DateOfMaturity
Date of Maturity
(i)
AmortizationPeriodStartDate
AMORTIZATION PERIOD Date From
(j)
AmortizationPeriodEndDate
AMORTIZATION PERIOD Date To
(k)
Outstanding (Total amount outstanding without reduction for amounts held by respondent)
(l)
Interest for Year Amount
(m)
1
Bonds (Account 221)
2
100, 5.875%
350,000,000
3,525,036
1,526,000
01/22/2003
02/01/2033
01/22/2003
02/01/2033
253,600,000
14,899,000
3
103, 5.900%
325,000,000
3,488,737
2,044,250
03/06/2006
03/15/2036
03/06/2006
03/15/2036
325,000,000
19,175,000
4
103B, 5.900%
300,000,000
1,048,534
12,435,000
03/22/2007
03/15/2036
03/22/2007
03/15/2036
300,000,000
17,700,000
5
107, 6.450%
450,000,000
4,468,683
1,359,000
01/16/2008
01/15/2038
01/16/2008
01/15/2038
450,000,000
29,025,000
6
113, 3.800%
350,000,000
3,497,084
623,000
10/01/2012
10/01/2042
10/01/2012
10/01/2042
350,000,000
13,300,000
7
114, 4.600%
350,000,000
4,224,661
791,000
08/19/2013
08/15/2043
08/19/2013
08/15/2043
350,000,000
16,100,000
8
116, 4.700%
350,000,000
3,670,733
115,500
01/10/2014
01/15/2044
01/10/2014
01/15/2044
350,000,000
16,450,000
9
117, 3.100%
250,000,000
2,675,378
212,500
11/10/2014
11/01/2024
11/10/2014
11/01/2024
250,000,000
7,750,000
10
118, 3.700%
400,000,000
4,497,729
03/02/2015
03/01/2045
03/02/2015
03/01/2045
400,000,000
14,800,000
11
119, 4.350%
450,000,000
5,643,725
3,501,000
11/19/2015
11/15/2045
11/19/2015
11/15/2045
450,000,000
19,575,000
12
120, 2.550%
500,000,000
4,325,512
06/27/2016
06/15/2026
06/27/2016
06/15/2026
500,000,000
12,750,000
13
121, 3.650%
700,000,000
7,630,653
4,543,000
06/27/2016
06/15/2046
06/27/2016
06/15/2046
700,000,000
25,550,000
14
122, 2.950%
350,000,000
3,084,480
959,000
08/23/2017
08/15/2027
08/23/2017
08/15/2027
350,000,000
10,325,000
15
123, 3.750%
650,000,000
7,187,392
1,625,000
08/23/2017
08/15/2047
08/23/2017
08/15/2047
650,000,000
24,375,000
16
124, 4.000%
800,000,000
8,806,005
152,000
02/20/2018
03/01/2048
02/20/2018
03/01/2048
800,000,000
32,000,000
17
125, 3.700%
550,000,000
5,724,371
1,320,000
08/14/2018
08/15/2028
08/14/2018
08/15/2028
550,000,000
20,350,000
18
126, 4.000%
400,000,000
5,320,038
3,256,000
02/19/2019
03/01/2049
02/19/2019
03/01/2049
400,000,000
16,000,000
19
127, 3.200%
300,000,000
3,958,928
2,349,000
11/12/2019
11/15/2049
11/12/2019
11/15/2049
300,000,000
9,600,000
20
128, 2.200%
350,000,000
3,831,604
1,064,000
02/18/2020
03/01/2030
02/18/2020
03/01/2030
350,000,000
7,700,000
21
129, 3.000%
650,000,000
8,523,636
897,000
02/18/2020
03/01/2050
02/18/2020
03/01/2050
650,000,000
19,500,000
22
130, 3.125%
700,000,000
9,221,373
952,000
03/09/2021
03/15/2051
03/09/2021
03/15/2051
700,000,000
21,875,000
23
131, 2.750%
450,000,000
4,695,716
94,500
08/12/2021
09/01/2051
08/12/2021
09/01/2051
450,000,000
12,375,000
24
132, 3.150%
300,000,000
3,265,761
384,000
03/15/2022
03/15/2032
03/15/2022
03/15/2032
300,000,000
9,450,000
25
133, 3.850%
450,000,000
5,905,442
796,500
03/15/2022
03/15/2052
03/15/2022
03/15/2052
450,000,000
17,325,000
26
134, 4.900%
400,000,000
4,419,289
1,336,000
01/10/2023
02/01/2033
01/10/2023
02/01/2033
400,000,000
19,110,000
27
135, 5.300%
575,000,000
7,643,212
1,397,250
01/10/2023
02/01/2053
01/10/2023
02/01/2053
575,000,000
29,713,125
28
Subtotal
(a)
11,700,000,000
130,283,712
43,732,500
11,603,600,000
456,772,125
29
Reacquired Bonds (Account 222)
30
31
32
33
Subtotal
34
Advances from Associated Companies (Account 223)
35
Subordinated Deferrable Interest Debentures, 6.350%,
206,186,000
2,256,515
186,000
03/17/2003
03/15/2033
03/17/2003
03/15/2033
206,186,000
13,092,811
36
ComEd FInancing III
37
Subtotal
206,186,000
2,256,515
186,000
206,186,000
13,092,811
38
Other Long Term Debt (Account 224)
39
40
41
42
Subtotal
33 TOTAL
11,906,186,000
11,809,786,000
(b)
469,864,936


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: BondsPrincipalAmountIssued
Changes in Account 221 during the year:
Issuances Retirements
First Mortgage Bonds $ 975,000,000  $ — 
The unamortized debt discount, premium or expense on reacquired debt are transferred to Account 189, Unamortized Loss on Reacquired Debt, or Account 257, Unamortized Gain on Reacquired Debt, as appropriate, and amortized to expense over the life of the new long-term debt issued to finance the debt redemption, and\or over the life of the original debt issuance if the debt is not refinanced.
(b) Concept: InterestExpenseOnLongTermDebtIssued
Total interest reported on Pages 256-257 $ 469,864,936 
Amortization of settled cash flow swaps - losses 519,507 
Total for Accounts 427 and 430 $ 470,384,443 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
  1. Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount.
  2. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members.
  3. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No.
Particulars (Details)
(a)
Amount
(b)
1
Net Income for the Year (Page 117)
1,094,078,343
2
Reconciling Items for the Year
3
4
Taxable Income Not Reported on Books
5
6
7
8
9
Deductions Recorded on Books Not Deducted for Return
10
See footnote for details
(a)
313,674,397
14
Income Recorded on Books Not Included in Return
15
16
17
18
19
Deductions on Return Not Charged Against Book Income
20
See footnote for details
(b)
1,321,266,801
27
Federal Tax Net Income
86,485,939
28
Show Computation of Tax:
29
Federal Income Tax at 21%
18,162,047
30
See footnote for details
(c)
118,149,521
31
Total
136,311,568
32
Federal Income Tax Acct 409.10
129,557,732
33
Federal Income Tax Acct 409.20
6,753,836


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: DeductionsRecordedOnBooksNotDeductedForReturn
Net Income for the Year (Page 117) $ 1,094,078,343 
Federal Income Tax 173,952,125 
State Income Tax 139,722,272 
Pre-tax Book Income $ 1,407,752,740 
(b) Concept: DeductionsOnReturnNotChargedAgainstBookIncome
Increase (Decrease) in Taxable Income Resulting From:
Removal Costs $ (187,217,362)
Mixed Service Costs — 
Repair Allowance - Unit of Property (629,442,685)
Bonus Depreciation — 
Depreciation 211,594,007 
CIAC 109,112,039 
AFUDC Equity (26,563,229)
AFUDC Debt (38,477,582)
Capitalized Interest 47,915,630 
Gain/Loss on Disposition of Property (37,319,251)
Other (Property) (6,320,290)
Regulatory Assets & Liabilities (851,762,214)
Pension/OPEB/SERP (474,726)
Accrued Liabilities 10,960,511 
Merger Commitment Deferrals — 
State Income Taxes Deductible 28,751,890 
Deferred Revenue (397,734)
Fines & Penalties — 
Other (Net) 48,374,195 
Total Schedule M's $ (1,321,266,801)
(c) Concept: ComputationOfTax
Federal Taxable Income $ 86,485,939 
Computation of Federal Income Tax:
Federal Income Tax on Current Year Income (21%) $ 18,162,047 
Current Corporate Minimum Tax 118,023,568 
Income Tax Credits Utilized (5,843,485)
Net Operating Loss Utilized — 
Return to Accrual 1,920,027 
Uncertain Tax Positions 2,930,709 
2016-2021 R&D Affirmative 1,118,702 
Federal Income Tax $ 136,311,568 
Federal Income Tax Account 409.10 $ 129,557,732 
Federal Income Tax Account 409.20 6,753,836 
Total $ 136,311,568 
Additional information in response to Instruction 2, Page 261:
The Respondent is a wholly-owned subsidiary of Exelon Corporation. The Respondent files a consolidated tax return with Exelon Corporation and Exelon Corporation's other subsidiaries. The consolidated federal income tax liability was allocated to the Respondent on a separate-return basis.

Corporate Alternative Minimum Tax Adjustment: This adjustment represents the difference between regular tax calculated at 21% of taxable income to the Corporate Alternative Minimum Tax calculated at 15% of Adjusted Financial Statement Income.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
  1. Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts.
  2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes.
  3. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts.
  4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
  5. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (d).
  6. Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses.
  7. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority.
  8. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (l) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts.
  9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
BALANCE AT BEGINNING OF YEAR BALANCE AT END OF YEAR DISTRIBUTION OF TAXES CHARGED
Line No.
DescriptionOfTaxesAccruedPrepaidAndCharged
Kind of Tax (See Instruction 5)
(a)
TypeOfTax
Type of Tax
(b)
TaxJurisdiction
State
(c)
TaxYear
Tax Year
(d)
TaxesAccrued
Taxes Accrued (Account 236)
(e)
PrepaidTaxes
Prepaid Taxes (Include in Account 165)
(f)
TaxesCharged
Taxes Charged During Year
(g)
TaxesPaid
Taxes Paid During Year
(h)
TaxAdjustments
Adjustments
(i)
TaxesAccrued
Taxes Accrued (Account 236)
(j)
PrepaidTaxes
Prepaid Taxes (Included in Account 165)
(k)
TaxesAccruedPrepaidAndCharged
Electric (Account 408.1, 409.1)
(l)
IncomeTaxesExtraordinaryItems
Extraordinary Items (Account 409.3)
(m)
AdjustmentsToRetainedEarnings
Adjustment to Ret. Earnings (Account 439)
(n)
TaxesIncurredOther
Other
(o)
1
Renewable Energy Tax
Other Taxes
IL
(a)
2023
695,421
0
4,625,837
4,638,737
682,521
4,625,837
2
Low Income Tax
Other Taxes
IL
(b)
2023
6,169,531
0
36,782,919
36,941,195
6,011,255
46,354,247
(q)
9,571,328
3
Energy Transition Assistance Charge
Other Taxes
IL
2023
9,022,399
0
58,936,053
60,205,034
7,753,418
58,936,053
4
Electricity Distribution Tax
Other Taxes
IL
(c)
2023
0
(o)
16,059,777
106,127,369
103,666,173
0
(p)
13,598,581
106,127,369
5
Chicago Infrastructure Maintenance Fee
Other Taxes
IL
(d)
2023
11,633,403
0
82,892,186
83,818,281
10,707,308
82,892,186
6
Evanston Infrastructure Maintenance Fee
Other Taxes
IL
(e)
2023
63,245
0
476,040
480,754
58,531
476,040
7
Municipal Utility Tax
Other Taxes
IL
(f)
2023
3,341,815
0
48,062
3,360,877
29,000
353,635
305,573
8
Cook County Parking Tax
Other Taxes
IL
(g)
2023
7,465
0
83,700
86,302
4,863
1,764
85,464
9
Chicago Transaction Tax
Other Taxes
IL
(h)
2023
19,202
0
546,428
522,869
42,761
238,328
308,100
10
Public Utility Fund
Other Taxes
IL
(i)
2023
1,369,065
0
1,460,045
1,341,769
1,487,341
1,460,045
11
Joliet Motor Fuel Tax
Other Taxes
IL
2023
0
0
118,379
4,772
113,607
118,379
12
Other Taxes
Other Taxes
IL
(j)
2023
2,688
0
251,690
10
248,992
0
251,690
13
Subtotal Other Tax
32,318,858
16,059,777
292,348,708
295,066,773
248,992
26,890,605
13,598,581
301,832,045
9,483,337
14
Unemployment Insurance (SUTA)
Unemployment Tax
IL
2022
30,499
0
30,499
0
15
Unemployment Insurance (SUTA)
Unemployment Tax
IL
2023
0
0
1,384,303
1,362,430
21,873
562,863
(r)
821,440
16
Unemployment Insurance (FUTA)
Unemployment Tax
Fed
2022
142,933
0
142,933
0
17
Unemployment Insurance (FUTA)
Unemployment Tax
Fed
2023
0
0
308,785
302,360
6,425
127,586
(s)
181,199
18
Subtotal Unemployment Tax
173,432
0
1,693,088
1,838,222
28,298
690,449
1,002,639
19
Use Tax
Sales And Use Tax
IL
(k)
2023
1,332,336
0
14,096,105
12,155,089
3,273,352
38,497
14,057,608
20
Chicago Use Tax
Sales And Use Tax
IL
(l)
2023
359,759
0
1,052,097
907,192
504,664
9,084
1,043,013
21
Sales Tax
Sales And Use Tax
IL
2023
0
162,492
358,432
376,920
0
180,980
358,432
22
Subtotal Sales And Use Tax
1,692,095
162,492
15,506,634
13,439,201
3,778,016
180,980
47,581
15,459,053
23
Federal Income Tax
Income Tax
Fed
(m)
2023
11,580,397
0
136,311,566
38,707,115
1,395,748
110,580,596
129,557,730
6,753,836
24
State Income Tax
Income Tax
IL
(n)
2023
3,260,658
0
10,137,127
28,290,203
367,907
21,045,827
11,432,424
1,295,297
25
Subtotal Income Tax
14,841,055
0
126,174,439
10,416,912
1,027,841
131,626,423
118,125,306
8,049,133
26
Federal Excise Tax - Heavy Highway
Excise Tax
Fed
2023
0
0
13,664
10,976
2,688
0
13,664
27
Subtotal Excise Tax
0
0
13,664
10,976
2,688
0
13,664
28
Franchise
Franchise Tax
IL
2022
0
1,547,544
1,547,544
0
1,547,544
29
Franchise
Franchise Tax
IL
2023
0
0
1,529,997
3,059,994
0
1,529,997
1,529,997
30
Subtotal Franchise Tax
0
1,547,544
3,077,541
3,059,994
0
1,529,997
3,077,541
31
Real Estate
Property Tax
IL
2022
36,205,407
0
3,918,487
32,286,920
0
3,918,487
32
Real Estate
Property Tax
IL
2023
0
0
36,255,000
36,255,000
35,921,223
(t)
333,777
33
Subtotal Other Property Tax
36,205,407
0
32,336,513
32,286,920
36,255,000
32,002,736
333,777
34
Vehicle License
Other License And Fees Tax
IL
2022
0
803,438
803,438
0
(u)
803,438
35
Vehicle License
Other License And Fees Tax
IL
2023
0
0
1,215,621
1,893,339
0
677,718
(v)
1,215,621
36
Vehicle License-Local
Other License And Fees Tax
IL
2022
0
79,461
79,461
0
(w)
79,461
37
Vehicle License-Local
Other License And Fees Tax
IL
2023
0
0
120,226
187,253
0
67,027
(x)
120,226
38
Subtotal Other License And Fees Tax
0
882,899
2,218,746
2,080,592
0
744,745
2,218,746
39
Insurance Contributions (FICA)
Payroll Tax
Fed
2022
10,922,863
0
10,922,863
0
40
Insurance Contributions (FICA)
Payroll Tax
Fed
2023
0
0
72,503,957
59,790,377
12,713,580
29,870,315
(y)
42,633,642
41
Subtotal Payroll Tax
10,922,863
0
72,503,957
70,713,240
12,713,580
29,870,315
42,633,642
40
TOTAL
96,153,710
18,652,712
545,873,290
428,912,830
776,161
211,291,922
16,054,303
485,659,637
60,213,653


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: TaxYear
The tax year for Renewable Energy Taxes accrued, prepaid, and charged during year also applies to the year 2022.
(b) Concept: TaxYear
The tax year for Low Income Taxes accrued, prepaid, and charged during year also applies to the year 2022.
(c) Concept: TaxYear
The tax year for Electricity Distribution Taxes accrued, prepaid, and charged during year also applies to the year 2022.
(d) Concept: TaxYear
The tax year for Chicago Infrastructure Maintenance Fee Taxes accrued, prepaid, and charged during year also applies to the year 2022.
(e) Concept: TaxYear
The tax year for Evanston Infrastructure Maintenance Fee Taxes accrued, prepaid, and charged during year also applies to the year 2022.
(f) Concept: TaxYear
The tax year for Municipal Utility Taxes accrued, prepaid, and charged during year also applies to 2022 and prior years.
(g) Concept: TaxYear
The tax year for Cook County Parking Taxes accrued, prepaid, and charged during year also applies to the year 2022.
(h) Concept: TaxYear
The tax year for Chicago Transaction Taxes accrued, prepaid, and charged during year also applies to the year 2022.
(i) Concept: TaxYear
The tax year for Public Utility Fund Taxes accrued, prepaid, and charged during year also applies to the year 2022.
(j) Concept: TaxYear
The tax year for Other Taxes accrued, prepaid, and charged during year also applies to the year 2022.
(k) Concept: TaxYear
The tax year for Use Taxes accrued, prepaid, and charged during year also applies to the year 2022.
(l) Concept: TaxYear
The tax year for Chicago Use Taxes accrued, prepaid, and charged during year also applies to the year 2022.
(m) Concept: TaxYear
The tax year for Federal Income Taxes accrued, prepaid, and charged during year also applies to the year 2022.
(n) Concept: TaxYear
The tax year for Illinois Income Taxes accrued, prepaid, and charged during year also applies to the year 2022.
(o) Concept: PrepaidTaxes
$6,567,897 recorded in Account 186 and $9,491,880 recorded in Account 143.
(p) Concept: PrepaidTaxes
$4,061,217 recorded in Account 186 and $9,537,364 recorded in Account 143.
(q) Concept: TaxesIncurredOther
Primarily Account 142.
(r) Concept: TaxesIncurredOther
Recorded to Account 184 and was subsequently allocated to various accounts.
(s) Concept: TaxesIncurredOther
Recorded to Account 184 and was subsequently allocated to various accounts.
(t) Concept: TaxesIncurredOther
Recorded to Account 408.2 for non-utility property and Account 131 for tax refunds.
(u) Concept: TaxesIncurredOther
Recorded to Account 184 and was subsequently allocated to various accounts.
(v) Concept: TaxesIncurredOther
Recorded to Account 184 and was subsequently allocated to various accounts.
(w) Concept: TaxesIncurredOther
Recorded to Account 184 and was subsequently allocated to various accounts.
(x) Concept: TaxesIncurredOther
Recorded to Account 184 and was subsequently allocated to various accounts.
(y) Concept: TaxesIncurredOther
Recorded to Account 184 and was subsequently allocated to various accounts.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)

Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.

Deferred for Year Allocations to Current Year's Income
Line No.
Account Subdivisions
(a)
Balance at Beginning of Year
(b)
Account No.
(c)
Amount
(d)
Account No.
(e)
Amount
(f)
Adjustments
(g)
Balance at End of Year
(h)
Average Period of Allocation to Income
(i)
ADJUSTMENT EXPLANATION
(j)
1
Electric Utility
2
3%
3
4%
45,646
1,598
47,244
45
4
7%
5
10%
5,984,465
1,170,385
4,814,080
32
6
Illinois ITC
1,630,491
367,902
49,416
1,948,977
41
8
TOTAL Electric (Enter Total of lines 2 thru 7)
7,660,602
367,902
1,218,203
6,810,301
9
Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10
`
47 OTHER TOTAL
48 GRAND TOTAL
7,660,602
367,902
1,218,203
6,810,301


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
OTHER DEFERRED CREDITS (Account 253)
  1. Report below the particulars (details) called for concerning other deferred credits.
  2. For any deferred credit being amortized, show the period of amortization.
  3. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
DEBITS
Line No.
Description and Other Deferred Credits
(a)
Balance at Beginning of Year
(b)
Contra Account
(c)
Amount
(d)
Credits
(e)
Balance at End of Year
(f)
1
(a)
Initial payments - contracts
3,940,593
3,940,593
2
(b)
Deferred rents
2,796
2,796
3
Long-term contracting services
633,644
633,644
4
Long-term renewable energy
5
contracts
79,458,407
10,531,763
37,330,996
106,257,640
6
Funds for Utility Job
7
Training Program (FEJA)
10,000,000
10,000,000
8
Other
429,609
319,944,200
319,799,273
574,536
47
TOTAL
93,605,831
330,475,963
357,130,269
120,260,137


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfOtherDeferredCredits
This item includes two contracts, with amortization periods starting April 1, 2000, and May 1, 2000, and continuing through March 31, 2030, and April 30, 2030, respectively.
(b) Concept: DescriptionOfOtherDeferredCredits
This item includes rents for various buildings, with amortization periods ranging from January 1, 1993 to December 31, 2023.
(c) Concept: DecreaseInOtherDeferredCreditsContraAccount
Other deferred credits are offset in Accounts 143, 242, 454, and 931.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report


End of:
2023
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1
Accelerated Amortization (Account 281)
2
Electric
3
Defense Facilities
4
Pollution Control Facilities
5
Other
5.1
Other (provide details in footnote):
8
TOTAL Electric (Enter Total of lines 3 thru 7)
9
Gas
10
Defense Facilities
11
Pollution Control Facilities
12
Other
12.1
Other (provide details in footnote):
15
TOTAL Gas (Enter Total of lines 10 thru 14)
16
Other
16.1
Other
16.2
Other
17
TOTAL (Acct 281) (Total of 8, 15 and 16)
18
Classification of TOTAL
19
Federal Income Tax
20
State Income Tax
21
Local Income Tax


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1 Account 282
2
Electric
4,272,205,881
99,870,086
109,710,598
Primarily 182
Primarily 182
708,758,694
4,971,124,063
3
Gas
4
Other (Specify)
5
Total (Total of lines 2 thru 4)
4,272,205,881
99,870,086
109,710,598
708,758,694
(a)
4,971,124,063
6
7
8
9
TOTAL Account 282 (Total of Lines 5 thru 8)
4,272,205,881
99,870,086
109,710,598
708,758,694
4,971,124,063
10
Classification of TOTAL
11
Federal Income Tax
2,957,767,938
14,668,903
87,091,788
554,001,208
3,410,008,455
12
State Income Tax
1,314,437,943
114,538,989
22,618,810
154,757,486
1,561,115,608
13
Local Income Tax


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxesOtherProperty
Description: Beginning Balance Ending Balance
AFUDC Equity $ 46,558,350  $ 63,954,946 
CIAC (252,901,666) (156,724,498)
Plant Deferred Taxes - FAS 109 4,478,549,197  5,063,893,615 
Total $ 4,272,205,881  $ 4,971,124,063 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
  1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Provide in the space below explanations for Page 276. Include amounts relating to insignificant items listed under Other.
  4. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1 Account 283
2
Electric
3
1,007,638,245
439,682,066
102,058,622
51,375,579
52,488,019
1,346,374,129
9 TOTAL Electric (Total of lines 3 thru 8)
1,007,638,245
439,682,066
102,058,622
51,375,579
52,488,019
1,346,374,129
10
Gas
11
12
13
14
15
16
17 TOTAL Gas (Total of lines 11 thru 16)
18 TOTAL Other
19 TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)
1,007,638,245
439,682,066
102,058,622
(a)
51,375,579
52,488,019
1,346,374,129
20
Classification of TOTAL
21
Federal Income Tax
683,115,695
345,909,637
79,988,264
190, 254, and 280
51,375,579
897,661,489
22
State Income Tax
324,522,550
93,772,429
22,070,358
190, 254, and 280
52,488,019
448,712,640
23
Local Income Tax
NOTES


FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxLiabilitiesOtherAdjustmentsDebitedToAccount
Description Beginning Balance Ending Balance
Pension Asset $ 340,928,200  $ 347,053,474 
Regulatory Asset 637,060,786  969,087,038 
Unamortized Loss on Required Debt 5,768,521  4,681,661 
Other 23,880,738  25,551,956 
Total $ 1,007,638,245  $ 1,346,374,129 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
OTHER REGULATORY LIABILITIES (Account 254)
  1. Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable.
  2. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes.
  3. For Regulatory Liabilities being amortized, show period of amortization.
DEBITS
Line No.
Description and Purpose of Other Regulatory Liabilities
(a)
Balance at Beginning of Current Quarter/Year
(b)
Account Credited
(c)
Amount
(d)
Credits
(e)
Balance at End of Current Quarter/Year
(f)
1
(a)
Decommissioning the Regulatory Agreement Units
2,659,759,104
294,653,077
2,954,412,181
2
Purchased Electricity - Over Recovery
10,884,703
10,957,955
73,252
3
Zero Emissions Program
1,570,047
1,570,047
4
Uncollectible Accounts Expense - Over Recovery
9,122,925
9,122,925
5
Deferred Income Taxes
2,005,066,274
111,707,199
284,311,635
2,177,670,710
6
Transmission Costs - Over Recovery
3,078,292
3,078,291
14,000,738
14,000,739
7
Renewable Portfolio Standard Costs - Rider REA
742,901,053
290,209,440
1,033,110,493
8
Renewable Portfolio Standard Costs - ACP Funds
66,797,859
2,259,310
69,057,169
9
Purchased Electricity - FERC 494 Refund
11,000,420
6,694,116
4,306,304
10
Parallel Operation of Retail Customer Generating Facilities Community Supply
3,126,680
3,126,680
11
Coal to Solar
912,324
912,324
41 TOTAL
5,499,295,974
146,183,961
900,431,159
6,253,543,172


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities
Line Item Rate Order Docket Number Or Recovery Mechanism Amortization Period
Decommissioning the Regulatory Agreement Units ICC Docket 00-0361 N/A
Purchased Electricity - Over Recovery ICC Docket No. 05-0159 & 18-1824 4 months from period end
Zero Emissions Program FEJA 9 months from each September
Uncollectible Accounts - Over Recovery ICC Docket Nos. 09-0433 & 20-0309 12 months from each June
Deferred Income Taxes ICC Order 18-0034 / FERC Order ER19-5 dated 4/26/19 Over the life of related assets
Transmission Costs - Over Recovery FERC Docket ER07-583 12 months from each June
Renewable Portfolio Standard Costs - Rider REA FEJA 9 months from each September
Renewable Portfolio Standard Costs - ACP Funds IPA LTRRP approved by ICC As approved by the IPA & ICC
Purchased Electricity - FERC 494 Refund FERC Order Docket No. EL05-121-009 7/1/2018 - 12/31/2025
Parallel Operation of Retail Customer Generating Facilities Community Supply - L ICC Docket 22-0305 Not determined yet
Coal to Solar ICC Docket 12-0298 1/1/2014-12/31/2028

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
Electric Operating Revenues
  1. The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages.
  2. Report below operating revenues for each prescribed account, and manufactured gas revenues in total.
  3. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month.
  4. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote.
  5. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2.
  6. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.)
  7. See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases.
  8. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts.
  9. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.
Title of Account
(a)
Operating Revenues Year to Date Quarterly/Annual
(b)
Operating Revenues Previous year (no Quarterly)
(c)
MEGAWATT HOURS SOLD Year to Date Quarterly/Annual
(d)
MEGAWATT HOURS SOLD Amount Previous year (no Quarterly)
(e)
AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly)
(f)
AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly)
(g)
1
SalesOfElectricityHeadingAbstract
Sales of Electricity
2
ResidentialSalesAbstract
(440) Residential Sales
3,862,275,761
3,438,822,318
26,022,565
27,818,982
3,732,459
3,713,755
3
CommercialAndIndustrialSalesAbstract
(442) Commercial and Industrial Sales
4
CommercialSalesAbstract
Small (or Comm.) (See Instr. 4)
2,027,198,786
1,250,665,489
28,705,593
29,766,349
391,406
390,683
5
IndustrialSalesAbstract
Large (or Ind.) (See Instr. 4)
896,098,046
39,704,209
26,707,834
26,904,297
1,875
1,888
6
PublicStreetAndHighwayLightingAbstract
(444) Public Street and Highway Lighting
45,348,653
32,602,901
454,308
470,865
4,796
4,846
7
OtherSalesToPublicAuthoritiesAbstract
(445) Other Sales to Public Authorities
8
SalesToRailroadsAndRailwaysAbstract
(446) Sales to Railroads and Railways
12,241,981
832,100
399,921
438,784
2
2
9
InterdepartmentalSalesAbstract
(448) Interdepartmental Sales
10
SalesToUltimateConsumersAbstract
TOTAL Sales to Ultimate Consumers
6,843,163,227
4,760,962,817
(f)(g)
82,290,221
(h)
85,399,277
4,130,538
4,111,174
11
SalesForResaleAbstract
(447) Sales for Resale
27,394,838
66,890,074
988,910
1,117,149
12
SalesOfElectricityAbstract
TOTAL Sales of Electricity
6,870,558,065
4,827,852,891
83,279,131
86,516,426
4,130,538
4,111,174
13
ProvisionForRateRefundsAbstract
(Less) (449.1) Provision for Rate Refunds
14
RevenuesNetOfProvisionForRefundsAbstract
TOTAL Revenues Before Prov. for Refunds
6,870,558,065
4,827,852,891
83,279,131
86,516,426
4,130,538
4,111,174
15
OtherOperatingRevenuesAbstract
Other Operating Revenues
16
ForfeitedDiscounts
(450) Forfeited Discounts
28,067,219
26,788,811
17
MiscellaneousServiceRevenues
(451) Miscellaneous Service Revenues
(a)
19,161,315
(d)
16,889,543
18
SalesOfWaterAndWaterPower
(453) Sales of Water and Water Power
19
RentFromElectricProperty
(454) Rent from Electric Property
87,133,133
95,183,203
20
InterdepartmentalRents
(455) Interdepartmental Rents
21
OtherElectricRevenue
(456) Other Electric Revenues
(b)
10,583,695
(e)
9,905,388
22
RevenuesFromTransmissionOfElectricityOfOthers
(456.1) Revenues from Transmission of Electricity of Others
831,947,358
821,355,622
23
RegionalTransmissionServiceRevenues
(457.1) Regional Control Service Revenues
24
MiscellaneousRevenue
(457.2) Miscellaneous Revenues
25
OtherMiscellaneousOperatingRevenues
Other Miscellaneous Operating Revenues
26
OtherOperatingRevenues
TOTAL Other Operating Revenues
976,892,720
970,122,567
27
ElectricOperatingRevenues
TOTAL Electric Operating Revenues
(c)
7,847,450,785
5,797,975,458
Line12, column (b) includes $
379,450,444
of unbilled revenues.
Line12, column (d) includes
158,499
MWH relating to unbilled revenues


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: MiscellaneousServiceRevenues
Account 451 (Miscellaneous Service Revenues) details are required by Page 300, Instruction No. 5
For the Years Ended December 31,
2023 2022
Meter Tampering $ 250,454  $ 140,771 
Temporary Service Revenues 3,905,485  2,879,367 
Electric Choice & Other Data Service Fees 27,612  17,772 
Turn On Charge 994,596  951,162 
Returned Check Fees 1,390,351  1,184,444 
Call Center Referral Services 114,569  109,042 
Deferred Payment Agreement Reinstatement Fees 2,540,168  3,028,990 
Energy Marketplace Services 209,095  327,838 
Interconnection Application & Facility Study Fees 8,514,928  6,340,056 
AMI Metering Opt-out Fees 1,061,222  1,213,360 
Other 152,835  696,741 
Total $ 19,161,315  $ 16,889,543 
(b) Concept: OtherElectricRevenue
Account 456 (Other Electric Revenues) details are required by Page 300, Instruction No. 5
For the Years Ended December 31,
2023 2022
Contracting & Engineering Study Services $ 9,794,273  $ 4,440,268 
IPP Electric Generation Studies reimbursements 517,586  3,206,326 
Beneficial Electrification Incentives (654,750)
Affiliate meter and other equipment rentals 12,611  87,298 
Affiliate maintenance revenues 913,975  2,171,496 
Total
$ 10,583,695  $ 9,905,388 
(c) Concept: ElectricOperatingRevenues
Total Electric Operating Revenues include the following amounts included in ComEd's 2023 delivery services formula rate reconciliation:
Total Delivery Service Operating Revenue
$ 3,395,873,000 
2023 Estimated Reconciliation Recorded as of December 31, 2023
562,000,000 
*
Low-Income Home Energy Assistance Program Revenue
48,814,000 
*
* Amount included in Total Delivery Service Operating Revenue reported above
Total Electric Operating Revenues include the following amounts included in ComEd's 2023 energy efficiency formula rate reconciliation:
Total Energy Efficiency Operating Revenue
$ 289,809,000 
2023 Estimated Reconciliation Recorded as of December 31, 2023
16,249,000 
*
* Amount included in Total Energy Efficiency Operating Revenue reported above
Total Electric Operating Revenues include the following amounts included in ComEd's 2023 distributed generation rebate formula rate reconciliation:
Total Distributed Generation Rebate Operating Revenue
$ 14,277,000 
2023 Estimated Reconciliation Recorded as of December 31, 2023
1,399,000 
*
* Amount included in Total Distributed Generation Rebate Operating Revenue reported above
(d) Concept: MiscellaneousServiceRevenues
Refer to the footnote for Line No. 17, column b.
(e) Concept: OtherElectricRevenue
Refer to the footnote for Line No. 21, column b.
(f) Concept: MegawattHoursSoldSalesToUltimateConsumers
MWh's for the Years Ended December 31,
2023 2022
Retail deliveries for Full Service
$ 29,964,172  $ 31,414,991 
Retail deliveries for Delivery Only
52,326,049 53,984,286
Total retail deliveries
$ 82,290,221  $ 85,399,277 
General Notes:
Full Service reflects deliveries to customers taking electric service under tariff rates. Delivery Only service reflects customers electing to receive electricity from Alternative Retail Electric Suppliers.
(g) Concept: MegawattHoursSoldSalesToUltimateConsumers
Retail deliveries for Full Service $ 29,964,172 
Retail deliveries for Delivery Only 52,326,049 
Total Sales to Ultimate Customers $ 82,290,221 
Refer to the footnote on Page 300, line No. 10, Column (d) for additional details.
(h) Concept: MegawattHoursSoldSalesToUltimateConsumers
Refer to the footnote for Line No. 10, column d.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
  1. The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.
Description of Service
(a)
Balance at End of Quarter 1
(b)
Balance at End of Quarter 2
(c)
Balance at End of Quarter 3
(d)
Balance at End of Year
(e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
TOTAL


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
(a)
BES - Residential
18,862,590
2,990,511,553
2,807,109
6,720
0.1585
2
BES - Residential Space Heating
1,518,069
195,873,224
151,055
10,050
0.1290
3
BES H - Hourly
390,285
46,940,326
42,261
9,235
0.1203
4
BES - Outdoor Lighting
5,152
1,048,293
5,308
971
0.2035
5
RDS - Delivery Service
5,413,007
411,203,718
726,726
7,448
0.0760
41 TOTAL Billed Residential Sales
26,189,103
3,645,577,114
3,732,459
7,017
0.1392
42 TOTAL Unbilled Rev. (See Instr. 6)
166,538
216,698,647
1.3012
43 TOTAL
26,022,565
3,862,275,761
3,732,459
6,972
0.1484


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfNumberAndTitleOfRateSchedule
The following legend is applicable for the various rates shown in column (a) -
BES is Basic Electric Service
RDS is Retail Delivery Service

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
BES - Fixed
4,681,598
677,644,781
218,663
21,410
0.1447
2
BES H - Hourly
3,333,985
290,402,792
8,095
411,857
0.0871
3
BES - Outdoor Lighting
27,067
3,154,968
5,208
5,197
0.1166
4
RDS - Delivery Service
20,746,468
938,715,897
159,440
130,121
0.0452
41 TOTAL Billed Small or Commercial
28,789,118
1,909,918,438
391,406
73,553
0.0663
42 TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)
83,525
117,280,348
1.4041
43 TOTAL Small or Commercial
28,705,593
2,027,198,786
391,406
73,340
0.0706


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
BES - Fixed
1,761
203,787
3
587,000
0.1157
2
BES H - Hourly
2,193,540
97,432,803
132
16,617,727
0.0444
3
BES - Outdoor Lighting
4
RDS - Delivery Service
24,456,702
760,217,324
1,740
14,055,576
0.0311
41 TOTAL Billed Large (or Ind.) Sales
26,652,003
857,853,914
1,875
14,214,402
0.0322
42 TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)
55,831
38,244,132
0.6850
43 TOTAL Large (or Ind.)
26,707,834
896,098,046
1,875
14,244,178
0.0336


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
BES H - Hourly
78,736
11,941,410
834
94,408
0.1517
2
BES - Outdoor Lighting
44,722
8,873,015
2,573
17,381
0.1984
3
RDS - Delivery Service
330,653
19,928,120
1,389
238,051
0.0603
41 TOTAL Billed Public Street and Highway Lighting
454,111
40,742,545
4,796
94,685
0.0897
42 TOTAL Unbilled Rev. (See Instr. 6)
197
4,606,108
23.3813
43 TOTAL
454,308
45,348,653
4,796
94,726
0.0998


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
RDS - railroads
364,385
9,620,772
2
182,192,500
0.0264
41 TOTAL Billed Sales To Railroads and Railways
364,385
9,620,772
2
182,192,500
0.0264
42 TOTAL Unbilled Rev. (See Instr. 6)
35,536
2,621,209
0.0738
43 TOTAL
399,921
12,241,981
2
199,960,500
0.0306


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
41 TOTAL Billed - All Accounts
82,448,720
6,463,712,783
4,130,538
19,961
0.0784
42 TOTAL Unbilled Rev. (See Instr. 6) - All Accounts
158,499
379,450,444
2.3940
43 TOTAL - All Accounts
(a)
82,290,221
6,843,163,227
4,130,538
19,922
0.0832


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: MegawattHoursOfElectricitySoldByRateSchedulesIncludingUnbilledRevenue
MWh's for the Years Ended December 31,
2023 2022
Retail Deliveries for Full Service 29,964,172  31,414,991 
Retail Deliveries for Delivery Only 52,326,049  53,984,286 
   Total Retail Deliveries 82,290,221  85,399,277 
General Notes:
Full Service reflects deliveries to customers taking electric service under tariff rates. Delivery Only service reflects customers electing to receive electricity from a competitive electric generation supplier.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
SALES FOR RESALE (Account 447)
  1. Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326).
  2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser.
  3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:

    RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers.

    LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract.

    IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years.

    SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less.

    LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit.

    IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years.

    OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote.

    AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment.

  4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k).
  5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided.
  6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.
  7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser.
  8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser.
  9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24.
  10. Footnote entries as required and provide explanations following all required data.
ACTUAL DEMAND (MW) REVENUE
Line No.
Name of Company or Public Authority (Footnote Affiliations)
(a)
Statistical Classification
(b)
FERC Rate Schedule or Tariff Number
(c)
Average Monthly Billing Demand (MW)
(d)
Average Monthly NCP Demand
(e)
Average Monthly CP Demand
(f)
Megawatt Hours Sold
(g)
Demand Charges ($)
(h)
Energy Charges ($)
(i)
Other Charges ($)
(j)
Total ($) (h+i+j)
(k)
1
Requirement Sales:
2
Non-Requirement Sales:
3
(a)
PJM Interconnection, LLC
988,910
27,394,838
27,394,838
15
Subtotal - RQ
16
Subtotal-Non-RQ
988,910
27,394,838
27,394,838
17 Total
988,910
27,394,838
27,394,838


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityReceivingElectricityPurchasedForResale
The MegaWatt Hours Sold and the associated Revenue Energy Charges reflect spot market sales.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
ELECTRIC OPERATION AND MAINTENANCE EXPENSES

If the amount for previous year is not derived from previously reported figures, explain in footnote.

Line No.
Account
(a)
Amount for Current Year
(b)
Amount for Previous Year (c)
(c)
1
PowerProductionExpensesAbstract
1. POWER PRODUCTION EXPENSES
2
SteamPowerGenerationAbstract
A. Steam Power Generation
3
SteamPowerGenerationOperationAbstract
Operation
4
OperationSupervisionAndEngineeringSteamPowerGeneration
(500) Operation Supervision and Engineering
5
FuelSteamPowerGeneration
(501) Fuel
6
SteamExpensesSteamPowerGeneration
(502) Steam Expenses
7
SteamFromOtherSources
(503) Steam from Other Sources
8
SteamTransferredCredit
(Less) (504) Steam Transferred-Cr.
9
ElectricExpensesSteamPowerGeneration
(505) Electric Expenses
10
MiscellaneousSteamPowerExpenses
(506) Miscellaneous Steam Power Expenses
11
RentsSteamPowerGeneration
(507) Rents
12
Allowances
(509) Allowances
13
SteamPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 4 thru 12)
14
SteamPowerGenerationMaintenanceAbstract
Maintenance
15
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
(510) Maintenance Supervision and Engineering
16
MaintenanceOfStructuresSteamPowerGeneration
(511) Maintenance of Structures
17
MaintenanceOfBoilerPlantSteamPowerGeneration
(512) Maintenance of Boiler Plant
18
MaintenanceOfElectricPlantSteamPowerGeneration
(513) Maintenance of Electric Plant
19
MaintenanceOfMiscellaneousSteamPlant
(514) Maintenance of Miscellaneous Steam Plant
20
SteamPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 15 thru 19)
21
PowerProductionExpensesSteamPower
TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)
22
NuclearPowerGenerationAbstract
B. Nuclear Power Generation
23
NuclearPowerGenerationOperationAbstract
Operation
24
OperationSupervisionAndEngineeringNuclearPowerGeneration
(517) Operation Supervision and Engineering
25
NuclearFuelExpense
(518) Fuel
26
CoolantsAndWater
(519) Coolants and Water
27
SteamExpensesNuclearPowerGeneration
(520) Steam Expenses
28
SteamFromOtherSourcesNuclearPowerGeneration
(521) Steam from Other Sources
29
SteamTransferredCreditNuclearPowerGeneration
(Less) (522) Steam Transferred-Cr.
30
ElectricExpensesNuclearPowerGeneration
(523) Electric Expenses
31
MiscellaneousNuclearPowerExpenses
(524) Miscellaneous Nuclear Power Expenses
32
RentsNuclearPowerGeneration
(525) Rents
33
NuclearPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of lines 24 thru 32)
34
NuclearPowerGenerationMaintenanceAbstract
Maintenance
35
MaintenanceSupervisionAndEngineeringNuclearPowerGeneration
(528) Maintenance Supervision and Engineering
36
MaintenanceOfStructuresNuclearPowerGeneration
(529) Maintenance of Structures
37
MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration
(530) Maintenance of Reactor Plant Equipment
38
MaintenanceOfElectricPlantNuclearPowerGeneration
(531) Maintenance of Electric Plant
39
MaintenanceOfMiscellaneousNuclearPlant
(532) Maintenance of Miscellaneous Nuclear Plant
40
NuclearPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 35 thru 39)
41
PowerProductionExpensesNuclearPower
TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)
42
HydraulicPowerGenerationAbstract
C. Hydraulic Power Generation
43
HydraulicPowerGenerationOperationAbstract
Operation
44
OperationSupervisionAndEngineeringHydraulicPowerGeneration
(535) Operation Supervision and Engineering
45
WaterForPower
(536) Water for Power
46
HydraulicExpenses
(537) Hydraulic Expenses
47
ElectricExpensesHydraulicPowerGeneration
(538) Electric Expenses
48
MiscellaneousHydraulicPowerGenerationExpenses
(539) Miscellaneous Hydraulic Power Generation Expenses
49
RentsHydraulicPowerGeneration
(540) Rents
50
HydraulicPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 44 thru 49)
51
HydraulicPowerGenerationContinuedAbstract
C. Hydraulic Power Generation (Continued)
52
HydraulicPowerGenerationMaintenanceAbstract
Maintenance
53
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
(541) Mainentance Supervision and Engineering
54
MaintenanceOfStructuresHydraulicPowerGeneration
(542) Maintenance of Structures
55
MaintenanceOfReservoirsDamsAndWaterways
(543) Maintenance of Reservoirs, Dams, and Waterways
56
MaintenanceOfElectricPlantHydraulicPowerGeneration
(544) Maintenance of Electric Plant
57
MaintenanceOfMiscellaneousHydraulicPlant
(545) Maintenance of Miscellaneous Hydraulic Plant
58
HydraulicPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 53 thru 57)
59
PowerProductionExpensesHydraulicPower
TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
60
OtherPowerGenerationAbstract
D. Other Power Generation
61
OtherPowerGenerationOperationAbstract
Operation
62
OperationSupervisionAndEngineeringOtherPowerGeneration
(546) Operation Supervision and Engineering
63
Fuel
(547) Fuel
64
GenerationExpenses
(548) Generation Expenses
64.1
OperationOfEnergyStorageEquipment
(548.1) Operation of Energy Storage Equipment
65
MiscellaneousOtherPowerGenerationExpenses
(549) Miscellaneous Other Power Generation Expenses
66
RentsOtherPowerGeneration
(550) Rents
67
OtherPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 62 thru 67)
68
OtherPowerGenerationMaintenanceAbstract
Maintenance
69
MaintenanceSupervisionAndEngineeringOtherPowerGeneration
(551) Maintenance Supervision and Engineering
70
MaintenanceOfStructures
(552) Maintenance of Structures
71
MaintenanceOfGeneratingAndElectricPlant
(553) Maintenance of Generating and Electric Plant
71.1
MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration
(553.1) Maintenance of Energy Storage Equipment
72
MaintenanceOfMiscellaneousOtherPowerGenerationPlant
(554) Maintenance of Miscellaneous Other Power Generation Plant
73
OtherPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 69 thru 72)
74
PowerProductionExpensesOtherPower
TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)
75
OtherPowerSuplyExpensesAbstract
E. Other Power Supply Expenses
76
PurchasedPower
(555) Purchased Power
1,742,592,887
2,630,988,513
76.1
PowerPurchasedForStorageOperations
(555.1) Power Purchased for Storage Operations
77
SystemControlAndLoadDispatchingElectric
(556) System Control and Load Dispatching
78
OtherExpensesOtherPowerSupplyExpenses
(557) Other Expenses
701,205,113
1,844,406,051
79
OtherPowerSupplyExpense
TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)
2,443,798,000
786,582,462
80
PowerProductionExpenses
TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)
2,443,798,000
786,582,462
81
TransmissionExpensesAbstract
2. TRANSMISSION EXPENSES
82
TransmissionExpensesOperationAbstract
Operation
83
OperationSupervisionAndEngineeringElectricTransmissionExpenses
(560) Operation Supervision and Engineering
26,886,530
25,668,154
85
LoadDispatchReliability
(561.1) Load Dispatch-Reliability
86
LoadDispatchMonitorAndOperateTransmissionSystem
(561.2) Load Dispatch-Monitor and Operate Transmission System
87
LoadDispatchTransmissionServiceAndScheduling
(561.3) Load Dispatch-Transmission Service and Scheduling
88
SchedulingSystemControlAndDispatchServices
(561.4) Scheduling, System Control and Dispatch Services
397,423,917
378,924,480
89
ReliabilityPlanningAndStandardsDevelopment
(561.5) Reliability, Planning and Standards Development
90
TransmissionServiceStudies
(561.6) Transmission Service Studies
24,238
436,849
91
GenerationInterconnectionStudies
(561.7) Generation Interconnection Studies
357,679
2,004,647
92
ReliabilityPlanningAndStandardsDevelopmentServices
(561.8) Reliability, Planning and Standards Development Services
15,259,248
15,989,983
93
StationExpensesTransmissionExpense
(562) Station Expenses
2,597,339
2,494,512
93.1
OperationOfEnergyStorageEquipmentTransmissionExpense
(562.1) Operation of Energy Storage Equipment
94
OverheadLineExpense
(563) Overhead Lines Expenses
390,000
30,731
95
UndergroundLineExpensesTransmissionExpense
(564) Underground Lines Expenses
324,074
418,731
96
TransmissionOfElectricityByOthers
(565) Transmission of Electricity by Others
10,659,454
8,919,712
97
MiscellaneousTransmissionExpenses
(566) Miscellaneous Transmission Expenses
(a)
25,596,876
(c)
20,493,947
98
RentsTransmissionElectricExpense
(567) Rents
1,428,087
1,301,817
99
TransmissionOperationExpense
TOTAL Operation (Enter Total of Lines 83 thru 98)
480,167,442
456,622,101
100
TransmissionMaintenanceAbstract
Maintenance
101
MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses
(568) Maintenance Supervision and Engineering
1,463,052
2,414,182
102
MaintenanceOfStructuresTransmissionExpense
(569) Maintenance of Structures
1,397,640
964,313
103
MaintenanceOfComputerHardwareTransmission
(569.1) Maintenance of Computer Hardware
299,080
279,203
104
MaintenanceOfComputerSoftwareTransmission
(569.2) Maintenance of Computer Software
1,804,347
2,692,024
105
MaintenanceOfCommunicationEquipmentElectricTransmission
(569.3) Maintenance of Communication Equipment
495,512
522,850
106
MaintenanceOfMiscellaneousRegionalTransmissionPlant
(569.4) Maintenance of Miscellaneous Regional Transmission Plant
107
MaintenanceOfStationEquipmentTransmission
(570) Maintenance of Station Equipment
24,010,672
23,928,282
107.1
MaintenanceOfEnergyStorageEquipmentTransmission
(570.1) Maintenance of Energy Storage Equipment
108
MaintenanceOfOverheadLinesTransmission
(571) Maintenance of Overhead Lines
25,958,394
24,589,105
109
MaintenanceOfUndergroundLinesTransmission
(572) Maintenance of Underground Lines
2,067,106
2,421,743
110
MaintenanceOfMiscellaneousTransmissionPlant
(573) Maintenance of Miscellaneous Transmission Plant
8,959,648
5,237,585
111
TransmissionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 101 thru 110)
66,455,451
63,049,287
112
TransmissionExpenses
TOTAL Transmission Expenses (Total of Lines 99 and 111)
546,622,893
519,671,388
113
RegionalMarketExpensesAbstract
3. REGIONAL MARKET EXPENSES
114
RegionalMarketExpensesOperationAbstract
Operation
115
OperationSupervision
(575.1) Operation Supervision
116
DayAheadAndRealTimeMarketAdministration
(575.2) Day-Ahead and Real-Time Market Facilitation
117
TransmissionRightsMarketAdministration
(575.3) Transmission Rights Market Facilitation
118
CapacityMarketAdministration
(575.4) Capacity Market Facilitation
119
AncillaryServicesMarketAdministration
(575.5) Ancillary Services Market Facilitation
120
MarketMonitoringAndCompliance
(575.6) Market Monitoring and Compliance
121
MarketFacilitationMonitoringAndComplianceServices
(575.7) Market Facilitation, Monitoring and Compliance Services
6,841,512
6,591,797
122
RentsRegionalMarketExpenses
(575.8) Rents
123
RegionalMarketOperationExpense
Total Operation (Lines 115 thru 122)
6,841,512
6,591,797
124
RegionalMarketExpensesMaintenanceAbstract
Maintenance
125
MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses
(576.1) Maintenance of Structures and Improvements
126
MaintenanceOfComputerHardware
(576.2) Maintenance of Computer Hardware
127
MaintenanceOfComputerSoftware
(576.3) Maintenance of Computer Software
128
MaintenanceOfCommunicationEquipmentRegionalMarketExpenses
(576.4) Maintenance of Communication Equipment
129
MaintenanceOfMiscellaneousMarketOperationPlant
(576.5) Maintenance of Miscellaneous Market Operation Plant
130
RegionalMarketMaintenanceExpense
Total Maintenance (Lines 125 thru 129)
131
RegionalMarketExpenses
TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)
6,841,512
6,591,797
132
DistributionExpensesAbstract
4. DISTRIBUTION EXPENSES
133
DistributionExpensesOperationAbstract
Operation
134
OperationSupervisionAndEngineeringDistributionExpense
(580) Operation Supervision and Engineering
26,273,230
24,656,189
135
LoadDispatching
(581) Load Dispatching
81,592
72,831
136
StationExpensesDistribution
(582) Station Expenses
1,367,288
1,378,866
137
OverheadLineExpenses
(583) Overhead Line Expenses
3,090,935
4,156,285
138
UndergroundLineExpenses
(584) Underground Line Expenses
20,013,201
20,068,180
138.1
OperationOfEnergyStorageEquipmentDistribution
(584.1) Operation of Energy Storage Equipment
139
StreetLightingAndSignalSystemExpenses
(585) Street Lighting and Signal System Expenses
2,328,703
1,499,284
140
MeterExpenses
(586) Meter Expenses
9,988,294
6,924,399
141
CustomerInstallationsExpenses
(587) Customer Installations Expenses
18,598,507
23,098,242
142
MiscellaneousDistributionExpenses
(588) Miscellaneous Expenses
106,833,329
119,740,754
143
RentsDistributionExpense
(589) Rents
4,283,656
3,092,721
144
DistributionOperationExpensesElectric
TOTAL Operation (Enter Total of Lines 134 thru 143)
192,858,735
204,687,751
145
DistributionExpensesMaintenanceAbstract
Maintenance
146
MaintenanceSupervisionAndEngineering
(590) Maintenance Supervision and Engineering
6,584,314
6,175,230
147
MaintenanceOfStructuresDistributionExpense
(591) Maintenance of Structures
2,043,511
2,072,901
148
MaintenanceOfStationEquipment
(592) Maintenance of Station Equipment
43,855,527
43,088,550
148.1
MaintenanceOfEnergyStorageEquipment
(592.2) Maintenance of Energy Storage Equipment
149
MaintenanceOfOverheadLines
(593) Maintenance of Overhead Lines
223,450,528
214,160,829
150
MaintenanceOfUndergroundLines
(594) Maintenance of Underground Lines
55,416,786
54,237,004
151
MaintenanceOfLineTransformers
(595) Maintenance of Line Transformers
6,818,851
5,789,737
152
MaintenanceOfStreetLightingAndSignalSystems
(596) Maintenance of Street Lighting and Signal Systems
2,433,605
2,376,160
153
MaintenanceOfMeters
(597) Maintenance of Meters
1,167,490
1,312,309
154
MaintenanceOfMiscellaneousDistributionPlant
(598) Maintenance of Miscellaneous Distribution Plant
9,962,073
9,344,810
155
DistributionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 146 thru 154)
351,732,685
338,557,530
156
DistributionExpenses
TOTAL Distribution Expenses (Total of Lines 144 and 155)
544,591,420
543,245,281
157
CustomerAccountsExpensesAbstract
5. CUSTOMER ACCOUNTS EXPENSES
158
CustomerAccountsExpensesOperationsAbstract
Operation
159
SupervisionCustomerAccountExpenses
(901) Supervision
336,289
378,241
160
MeterReadingExpenses
(902) Meter Reading Expenses
16,440,582
18,245,045
161
CustomerRecordsAndCollectionExpenses
(903) Customer Records and Collection Expenses
197,074,440
176,980,949
162
UncollectibleAccounts
(904) Uncollectible Accounts
44,780,156
24,305,686
163
MiscellaneousCustomerAccountsExpenses
(905) Miscellaneous Customer Accounts Expenses
164
CustomerAccountExpenses
TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)
258,631,467
219,909,921
165
CustomerServiceAndInformationalExpensesAbstract
6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166
CustomerServiceAndInformationalExpensesOperationAbstract
Operation
167
SupervisionCustomerServiceAndInformationExpenses
(907) Supervision
168
CustomerAssistanceExpenses
(908) Customer Assistance Expenses
37,985,667
31,907,881
169
InformationalAndInstructionalAdvertisingExpenses
(909) Informational and Instructional Expenses
12,655,336
12,270,186
170
MiscellaneousCustomerServiceAndInformationalExpenses
(910) Miscellaneous Customer Service and Informational Expenses
171
CustomerServiceAndInformationExpenses
TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)
50,641,003
44,178,067
172
SalesExpenseAbstract
7. SALES EXPENSES
173
SalesExpenseOperationAbstract
Operation
174
SupervisionSalesExpense
(911) Supervision
175
DemonstratingAndSellingExpenses
(912) Demonstrating and Selling Expenses
176
AdvertisingExpenses
(913) Advertising Expenses
177
MiscellaneousSalesExpenses
(916) Miscellaneous Sales Expenses
178
SalesExpenses
TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)
179
AdministrativeAndGeneralExpensesAbstract
8. ADMINISTRATIVE AND GENERAL EXPENSES
180
AdministrativeAndGeneralExpensesOperationAbstract
Operation
181
AdministrativeAndGeneralSalaries
(920) Administrative and General Salaries
54,461,993
48,851,634
182
OfficeSuppliesAndExpenses
(921) Office Supplies and Expenses
24,072,201
22,713,540
183
AdministrativeExpensesTransferredCredit
(Less) (922) Administrative Expenses Transferred-Credit
55,017,767
42,518,604
184
OutsideServicesEmployed
(923) Outside Services Employed
247,635,892
220,765,519
185
PropertyInsurance
(924) Property Insurance
2,272,568
2,291,440
186
InjuriesAndDamages
(925) Injuries and Damages
20,785,264
8,642,655
187
EmployeePensionsAndBenefits
(926) Employee Pensions and Benefits
74,976,530
85,300,246
188
FranchiseRequirements
(927) Franchise Requirements
37,509,540
41,385,838
189
RegulatoryCommissionExpenses
(928) Regulatory Commission Expenses
9,224,259
2,954,820
190
DuplicateChargesCredit
(929) (Less) Duplicate Charges-Cr.
37,509,540
41,385,838
191
GeneralAdvertisingExpenses
(930.1) General Advertising Expenses
8,455,675
7,226,630
192
MiscellaneousGeneralExpenses
(930.2) Miscellaneous General Expenses
10,424,781
14,560,234
193
RentsAdministrativeAndGeneralExpense
(931) Rents
2,721,104
3,568,021
194
AdministrativeAndGeneralOperationExpense
TOTAL Operation (Enter Total of Lines 181 thru 193)
400,012,500
374,356,135
195
AdministrativeAndGeneralExpensesMaintenanceAbstract
Maintenance
196
MaintenanceOfGeneralPlant
(935) Maintenance of General Plant
41,192,422
42,605,388
197
AdministrativeAndGeneralExpenses
TOTAL Administrative & General Expenses (Total of Lines 194 and 196)
441,204,922
416,961,523
198
OperationsAndMaintenanceExpensesElectric
TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)
(b)
4,292,331,217
(d)
2,537,140,439


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: MiscellaneousTransmissionExpenses
Included in Account 566 (Miscellaneous Transmission Expense) are expenses (benefits) associated with the following:
For the Years Ended December 31,
2023 2022
PJM Interconnection, LLC (PJM) Related Activity:
PJM Transmission benefit $ —  $ (617,438)
Other (1,318,398) (5,888,919)
Sub-total (PJM related activity) $ (1,318,398) $ (6,506,357)
Other Miscellaneous transmission expenses 26,915,274  27,000,304 
Total for Account 566 $ 25,596,876  $ 20,493,947 
Expenses associated with PJM were recorded in the following accounts:
For the Years Ended December 31,
2023 2022
Account 555 $ 691,537,366  $ 1,308,487,075 
Account 561.4 397,423,917  378,924,480 
Account 561.8 15,259,248  15,989,983 
Account 566 (1,318,398) (6,506,357)
Account 575.7 6,841,513  6,591,797 
Total $ 1,109,743,646  $ 1,703,486,978 
(b) Concept: OperationsAndMaintenanceExpensesElectric
Includes expenses for the year 2023 related to the following:
                  Postretirement benefit expenses, other than pension expenses (PBOP), of ($5,587,089)
                  Power procurement expenses of $295,182 in A&G accounts 920-935.
(c) Concept: MiscellaneousTransmissionExpenses
Refer to the footnote for Line No. 97, Column (b).
(d) Concept: OperationsAndMaintenanceExpensesElectric
Includes expenses for the year 2022 related to the following:
                  Postretirement benefit expenses, other than pension expenses (PBOP), of ($1,629,074)
                  Power procurement expenses of $504,677 in A&G accounts 920-935.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
PURCHASED POWER (Account 555)
  1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges.
  2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
  3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:

    RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers.

    LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract.

    IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years.

    SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less.

    LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit.

    IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years.

    EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges.

    OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment.

    AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment.

  4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided.
  5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.
  6. Report in column (g) the megawatthours shown on bills rendered to the respondent, excluding purchases for energy storage. Report in column (h) the megawatthours shown on bills rendered to the respondent for energy storage purchases. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange.
  7. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote.
  8. The data in columns (g) through (n) must be totaled on the last line of the schedule. The total amount in columns (g) and (h) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13.
  9. Footnote entries as required and provide explanations following all required data.
Actual Demand (MW) POWER EXCHANGES COST/SETTLEMENT OF POWER
Line No.
NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Name of Company or Public Authority (Footnote Affiliations)
(a)
StatisticalClassificationCode
Statistical Classification
(b)
RateScheduleTariffNumber
Ferc Rate Schedule or Tariff Number
(c)
AverageMonthlyBillingDemand
Average Monthly Billing Demand (MW)
(d)
AverageMonthlyNonCoincidentPeakDemand
Average Monthly NCP Demand
(e)
AverageMonthlyCoincidentPeakDemand
Average Monthly CP Demand
(f)
MegawattHoursPurchasedOtherThanStorage
MegaWatt Hours Purchased (Excluding for Energy Storage)
(g)
MegawattHoursPurchasedForEnergyStorage
MegaWatt Hours Purchased for Energy Storage
(h)
EnergyReceivedThroughPowerExchanges
MegaWatt Hours Received
(i)
EnergyDeliveredThroughPowerExchanges
MegaWatt Hours Delivered
(j)
DemandChargesOfPurchasedPower
Demand Charges ($)
(k)
EnergyChargesOfPurchasedPower
Energy Charges ($)
(l)
OtherChargesOfPurchasedPower
Other Charges ($)
(m)
SettlementOfPower
Total (k+l+m) of Settlement ($)
(n)
1
(a)
AEP Energy Partners, Inc.
571,400
33,376,194
33,376,194
2
Dynegy Marketing ad Trade, LLC
2,971,325
164,158,891
164,158,891
3
Enel Trading North America, LLC
17,800
912,640
912,640
4
(b)
Constellation Energy Generation, LLC
2,674,800
97,905,145
97,905,145
5
J. ARON & COMPANY LLC
1,646,325
176,841,656
176,841,656
6
Macquarie Energy, LLC
1,227,850
80,510,938
80,510,938
7
Midwest Generation, LLC
955,400
27,425,920
27,425,920
8
Morgan Stanley Capital Group Inc.
1,593,575
44,483,018
44,483,018
9
Mercuria Energy America, LLC
48,400
1,430,916
1,430,916
10
NextEra Energy Marketing, LLC
958,900
46,691,254
46,691,254
11
NRG Power Marketing, LLC
1,969,925
116,269,182
116,269,182
12
Shell Energy North America (US), L.P.
1,304,425
66,808,732
66,808,732
13
Tidal
364,225
27,269,294
27,269,294
14
TransAlta Energy Marketing (U.S.) Inc.
740,525
61,946,251
61,946,251
15
Vitol Inc.
102,200
14,170,120
14,170,120
16
Cogeneration
379,141
24,664,975
24,664,975
17
PJM Interconnection, LLC
15,229,684
691,537,365
691,537,365
18
Company Use
19
Deferred Energy Costs
(c)
16,093,934
16,093,934
20
Other Net Metering Arrangements
213,570
(d)
9,358,316
9,358,316
21
Other Miscellaneous Adjustments
72,926,014
72,926,014
15 TOTAL
(e)
32,969,470
0
0
0
1,676,402,491
66,190,396
1,742,592,887


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
This footnote pertains to Column (a) of Pages 326. Refer to Notes to Financial Statements, Page 122-123, for information regarding the Respondent's energy procurement for retail customers pursuant to the ICC-approved procurement process.
(b) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Constellation Energy Generation, LLC (formerly Exelon Generation Company, LLC) was a subsidiary of Exelon Corporation until February 1, 2022.
(c) Concept: OtherChargesOfPurchasedPower
The Respondent's electricity costs are recoverable or refundable under the Respondent's ICC approved rates. The Respondent recovers or refunds the difference between the actual cost of electricity and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates.
(d) Concept: OtherChargesOfPurchasedPower
Represents the settlement activity associated with the 20-year floating-to-fixed energy swap contracts entered into on December 17, 2010 with unaffiliated suppliers for the procurement of long-term renewable energy and associated RECs.
(e) Concept: MegawattHoursPurchasedOtherThanStorage
Reflects utility zone load, which includes the following amounts purchased by ComEd to serve its Full Service customers.
1Q 2023 Month MWhs
January 2,869,396 
February 2,610,865 
March 2,657,711 
Quarter Total 8,137,972 
2Q 2023 Month MWhs
April 2,177,825 
May 2,276,382 
June 2,770,877 
Quarter Total 7,225,084 
3Q 2023 Month MWhs
July 3,617,373 
August 3,868,648 
September 3,161,863 
Quarter Total 10,647,884 
4Q 2023 Month MWhs
October 1,946,443 
November 2,363,638 
December 2,648,449 
Quarter Total 6,958,530 
YTD Total 32,969,470 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
  1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter.
  2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c).
  3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c).
  4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
  5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided.
  6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract.
  7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain.
  8. Report in column (i) and (j) the total megawatthours received and delivered.
  9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (0) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
  10. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively.
  11. Footnote entries and provide explanations following all required data.
TRANSFER OF ENERGY REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Line No.
PaymentByCompanyOrPublicAuthority
Payment By (Company of Public Authority) (Footnote Affiliation)
(a)
TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName
Energy Received From (Company of Public Authority) (Footnote Affiliation)
(b)
TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName
Energy Delivered To (Company of Public Authority) (Footnote Affiliation)
(c)
StatisticalClassificationCode
Statistical Classification
(d)
RateScheduleTariffNumber
Ferc Rate Schedule of Tariff Number
(e)
TransmissionPointOfReceipt
Point of Receipt (Substation or Other Designation)
(f)
TransmissionPointOfDelivery
Point of Delivery (Substation or Other Designation)
(g)
BillingDemand
Billing Demand (MW)
(h)
TransmissionOfElectricityForOthersEnergyReceived
Megawatt Hours Received
(i)
TransmissionOfElectricityForOthersEnergyDelivered
Megawatt Hours Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
RevenuesFromTransmissionOfElectricityForOthers
Total Revenues ($) (k+l+m)
(n)
1
PJM Interconnection L.L.C.
(a)
116,086,890
116,086,890
2
PJM Interconnection L.L.C.
(b)
100,815,748
100,815,748
3
PJM Interconnection L.L.C.
(c)
6,395,269
6,395,269
35 TOTAL
0
0
0
223,297,907
223,297,907


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
Network Integration Transmission Service (NITS) for Third Party Suppliers (difference between NITS Credits and Provider of Last Resort Network Integration Charges).
(b) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
Network Integration Transmission Service (NITS) for Self.
(c) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
The details of the Other Transmission Services are as follows:
Transmission Owner Scheduling, System Control and Dispatch Service $ 5,245,826 
Other Supporting Facilities 1,149,443 
$ 6,395,269 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
TRANSMISSION OF ELECTRICITY BY ISO/RTOs
  1. Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO.
  2. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a).
  3. In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
  4. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided.
  5. In column (d) report the revenue amounts as shown on bills or vouchers.
  6. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No.
Payment Received by (Transmission Owner Name)
(a)
Statistical Classification
(b)
FERC Rate Schedule or Tariff Number
(c)
Total Revenue by Rate Schedule or Tariff
(d)
Total Revenue
(e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
40
TOTAL


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
  1. Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter.
  2. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported.
  3. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:
    FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications.
  4. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service.
  5. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
  6. Enter ""TOTAL"" in column (a) as the last line.
  7. Footnote entries and provide explanations following all required data.
TRANSFER OF ENERGY EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.
NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers
Name of Company or Public Authority (Footnote Affiliations)
(a)
StatisticalClassificationCode
Statistical Classification
(b)
TransmissionOfElectricityByOthersEnergyReceived
MegaWatt Hours Received
(c)
TransmissionOfElectricityByOthersEnergyDelivered
MegaWatt Hours Delivered
(d)
DemandChargesTransmissionOfElectricityByOthers
Demand Charges ($)
(e)
EnergyChargesTransmissionOfElectricityByOthers
Energy Charges ($)
(f)
OtherChargesTransmissionOfElectricityByOthers
Other Charges ($)
(g)
ChargesForTransmissionOfElectricityByOthers
Total Cost of Transmission ($)
(h)
1
Commonwealth Edison
2
Company of Indiana, Inc.
(a)
10,659,454
10,659,454
TOTAL
0
0
0
0
10,659,454
10,659,454


FOOTNOTE DATA

(a) Concept: OtherChargesTransmissionOfElectricityByOthers
Commonwealth Edison Company of Indiana, Inc., a 100% owned subsidiary of the Respondent, provides transmission service to the Respondent under a service agreement.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.
Description
(a)
Amount
(b)
1
IndustryAssociationDues
Industry Association Dues
1,055,281
2
NuclearPowerResearchExpenses
Nuclear Power Research Expenses
3
OtherExperimentalAndGeneralResearchExpenses
Other Experimental and General Research Expenses
4
PublicationAndDistributionExpensesForSecuritiesToStockholders
Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities
5
OtherMiscellaneousGeneralExpenses
Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6
Accrued Vacation Pay
1,004,146
7
Environmental remediation expenses
1,914,189
8
Other environmental expenses
67,598
9
Director's fees and expenses
598,141
10
Sale or write-off of materials and supplies
88,591
11
Bank Fees
984,069
12
Undistributed employee expenses
117,541
13
Information technology upgrades expenses
1,160,716
14
Residential Time of Use Pricing Pilot Development and Operation
521,052
15
Smart meter network professional services and other costs
524,247
16
Miscellaneous Adjustments
2,801,474
46
MiscellaneousGeneralExpenses
TOTAL
10,424,781


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
  1. Report in section A for the year the amounts for: (b) Depreciation Expense (Account 403); (c) Depreciation Expense for Asset Retirement Costs (Account 403.1); (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405).
  2. Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year.
  3. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year.
    Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used.
    In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used.
    For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type of mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis.
  4. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
A. Summary of Depreciation and Amortization Charges
Line No.
FunctionalClassificationAxis
Functional Classification
(a)
DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments
Depreciation Expense (Account 403)
(b)
DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments
Depreciation Expense for Asset Retirement Costs (Account 403.1)
(c)
AmortizationOfLimitedTermPlantOrProperty
Amortization of Limited Term Electric Plant (Account 404)
(d)
AmortizationOfOtherElectricPlant
Amortization of Other Electric Plant (Acc 405)
(e)
DepreciationAndAmortization
Total
(f)
1
Intangible Plant
(a)
99,413,564
99,413,564
2
Steam Production Plant
3
Nuclear Production Plant
4
Hydraulic Production Plant-Conventional
5
Hydraulic Production Plant-Pumped Storage
6
Other Production Plant
7
Transmission Plant
163,683,783
195,202
92,854
163,971,839
8
Distribution Plant
720,489,035
1,396,949
197,459
722,083,443
9
Regional Transmission and Market Operation
10
General Plant
121,879,988
266,772
956,284
(b)
123,103,044
11
Common Plant-Electric
12
TOTAL
1,006,052,806
1,858,923
100,660,161
1,108,571,890
B. Basis for Amortization Charges
See footnote data for Page 336, Line No. 1, Column (d) for required information.
C. Factors Used in Estimating Depreciation Charges
Line No.
AccountNumberFactorsUsedInEstimatingDepreciationCharges
Account No.
(a)
DepreciablePlantBase
Depreciable Plant Base (in Thousands)
(b)
UtilityPlantEstimatedAverageServiceLife
Estimated Avg. Service Life
(c)
UtilityPlantNetSalvageValuePercentage
Net Salvage (Percent)
(d)
UtilityPlantAppliedDepreciationRate
Applied Depr. Rates (Percent)
(e)
MortalityCurveType
Mortality Curve Type
(f)
UtilityPlantWeightedAverageRemainingLife
Average Remaining Life
(g)
12
6,579,016
63 years
44
(e)
2.53
47 years, 8 months, 50 days
13
14
18,759,702
54 years
46
(f)
2.75
43 years, 3 months, 10 days
15
4,112,684
59 years
38
(g)
2.5
44 years, 5 months, 14 days
16
1,604,152
35 years
2.33
SQ
22 years, 3 months, 19 days
17
1,006
0 years
0 years
18
794,275
15 years
15
7.87
SQ
9 years, 6 months
19
55,801
35 years
10
3.29
SQ
24 years, 3 months, 19 days
20
21
778,676
50 years
20
2.6
R1
41 years, 6 months
22
118,827
5 years
19.99
SQ
2 years, 10 months, 25 days
23
41,839
15 years
6.67
SQ
9 years, 10 months, 25 days
24
421
10 years
10
SQ
5 years
25
26
2,689
8 years
10
10.92
R3
3 years, 10 months, 25 days
27
1,087
15 years
10
1.24
R2.5
3 years, 2 months, 13 days
28
23,965
18 years
15
4.41
S0
13 years, 6 months
29
92,168
10 years
10
7.45
R1.5
6 years
30
350,638
14 years
10
5.86
S1.5
9 years, 2 months, 13 days
31
8,264
15 years
6.67
SQ
10 years, 1 month, 5 days
32
277,734
25 years
4
SQ
14 years, 8 months, 13 days
33
17,479
15 years
6.67
SQ
11 years, 7 months, 5 days
34
7,792
15 years
5
6.63
L3
6 years, 7 months, 5 days
35
252,152
15 years
10
7.33
SQ
9 years, 4 months, 25 days
36
179,829
10 years
10
11
SQ
5 years, 1 month, 5 days
37
771,710
20 years
10
2.27
L2
14 years, 3 months, 19 days
38
44
12 years
10
9.17
SQ
6 years, 6 months
39
22,529
15 years
6.67
SQ
10 years, 8 months, 50 days
40


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: AmortizationOfLimitedTermPlantOrProperty
The amortization charges shown in Column (d), Line 1 - Intangible Plant represent the straight-line amortization of the development costs of the following software:
System Avg Remaining Life in Years
CTA PHI Systems 0*
Maint Inspect SW 0*
Oracle Upgrade SW 0*
ComEd Care Ctr SW 0*
Voltage Assessment 0*
LED Streetlights SW 0*
BIDA Smrt Enrgy EOL 0*
Fusion SW 1
Common MDM 1
BIDA Customer Proj 1
BIDA SESII Enhance 1
Robotic Process SW 1
Digital Strgy Epay 1
EU North Star RE 1
CIS Transformation 2
EU Custon Analytic 2
ISUM 2020 SW 2
EMS Implementation 2
BIDA AMI 3
GIS 3
EU SW Electric 3
Grid FR 3
Misc Comp Software FR 3
SES 3
BIDA Grid EOL 3
Mobile App 5
IVR Convergence 5
EU Dig Prgm: Web 5
Port Mgmt Tool 5
SAM SW 5
UI Plan SW 5
*Fully amortized during 2023.

The amortization charges shown in Column (d), Line 1 - Intangible Plant, represent the straight line amortization of the development costs related to software. See note for Column (d) line 1 for additional details regarding the system software included in Intangible Plant. Note that software is typically amortized over a 5 year period unless another life is deemed more appropriate.

The amortization charges shown in Column (d), Line 7 and Line 8 represent the amortization of costs for three Transmission Right-of Way Easements and two Distribution Right-of Way Easement, respectively, based on the periods covered by the Easements.

The amortization charges shown in Column (d), Line 10 - General Plant represent the amortization of three leasehold improvements over the lives of the respective leases.
(b) Concept: DepreciationAndAmortization
The amount of depreciation expense associated with Account 397 (Communication Equipment) for the year 2023 is $57,606,472.21 - 28.56% of such amount is directly assignable to the Transmission function.
(c) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
This note pertains to all plant accounts on Page 337 in Column (a), excluding transportation.

Depreciation is computed monthly by taking the monthly depreciation rate times the average depreciable plant-in-service balances at the beginning and end of each month. The amounts shown in Column (b) are the annual average depreciable plan-in-service balances computed by dividing the sum of the monthly average plant-in-service balances for the year by twelve.
(d) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
General Notes for Page 337:

Page 337, Section C excludes all amortized Limited Term Plant (software, leasehold improvements, right of ways, etc.) as referenced in the footnote for Page 336, Line No. 1, Column (d).

The Company provides depreciation on a straight-line basis by amortizing the cost of depreciable electric plant-in-service over estimated service lives for each class of plant.

The annual average depreciable plant base for [a] Transmission, [b] Distribution - excluding HVD, Line Transformers and Meters, [c] Distribution High Voltage is reduced by $16,454,447, $49,180,967 and $21,065,181, respectively, related to estimated unrecorded retirements of certain plant-in-service.
(e) Concept: UtilityPlantAppliedDepreciationRate
A composite rate is calculated for all depreciation groups; therefore, an individual mortality curve is not available.
(f) Concept: UtilityPlantAppliedDepreciationRate
A composite rate is calculated for all depreciation groups; therefore, an individual mortality curve is not available.
(g) Concept: UtilityPlantAppliedDepreciationRate
A composite rate is calculated for all depreciation groups; therefore, an individual mortality curve is not available.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
REGULATORY COMMISSION EXPENSES
  1. Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous years, if being amortized) relating to format cases before a regulatory body, or cases in which such a body was a party.
  2. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization of amounts deferred in previous years.
  3. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization.
  4. List in columns (f), (g), and (h), expenses incurred during the year which were charged currently to income, plant, or other accounts.
  5. Minor items (less than $25,000) may be grouped.
EXPENSES INCURRED DURING YEAR AMORTIZED DURING YEAR
CURRENTLY CHARGED TO
Line No.
RegulatoryCommissionDescription
Description (Furnish name of regulatory commission or body the docket or case number and a description of the case)
(a)
RegulatoryExpensesAssessedByRegulatoryCommission
Assessed by Regulatory Commission
(b)
RegulatoryExpensesOfUtility
Expenses of Utility
(c)
RegulatoryCommissionExpensesAmount
Total Expenses for Current Year (b) + (c)
(d)
OtherRegulatoryAssetsRegulatoryCommissionExpenses
Deferred in Account 182.3 at Beginning of Year
(e)
NameOfDepartmentRegulatoryCommissionExpensesCharged
Department
(f)
AccountNumberRegulatoryCommissionExpensesCharged
Account No.
(g)
RegulatoryComissionExpensesIncurredAndCharged
Amount
(h)
RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets
Deferred to Account 182.3
(i)
DeferredRegulatoryCommissionExpensesAmortizedInContraAccount
Contra Account
(j)
DeferredRegulatoryCommissionExpensesAmortized
Amount
(k)
OtherRegulatoryAssetsRegulatoryCommissionExpenses
Deferred in Account 182.3 End of Year
(l)
1
Illinois Commerce Commission
2
-------------------------------------
3
Docket Nos. -
4
19-0875, 19-0940, 19-1064, 20-0627, 20-0703, 20-0629
5
21-0160, 21-0416, 21-0530, 21-0546, 21-0544, 21-0761
6
21-0777, 22-0769, 22-0727, 22-0424, 22-0160, 22-0076
7
23-0834, 23-0826, 23-0770, 23-0743, 23-0744, 23-0734,
8
23-0731, 23-0722, 23-0710, 23-0675, 23-0622, 23-0610,
9
23-0675, 23-0622, 23-0610, 23-0592, 23-0574, 23-0553
10
23-0503, 23-0504, 23-0476, 23-0444, 23-0407, 23-0381
11
23-0355, 23-0341, 23-0269, 23-0197, 23-0592
12
Various complaint and petition matters
144,000
144,000
144,000
13
Docket No. 23-0345 Annual Formula rate update and revenue
14
requirement reconciliation
331,147
331,147
331,147
15
Docket No.  22-0067  Performance Metrics
75,200
75,200
75,200
16
Docket No.  docket anticipated  Equitable Energy Upgrade Program
36,400
36,400
36,400
17
Docket No.  docket anticipated  Low Income Rate Study
404,731
404,731
404,731
18
Docket No.  docket anticipated  Value of DER Proceeding
29,666
29,666
29,666
19
Docket No. 23-0055 Verified Petition for Approval
20
of a Multi-Year Rate Plan
3,627,673
3,627,673
2,160,188
6,823,599
5,128,081
2,067,098
5,221,171
21
Annual Ethics & Compliance Fee
500,000
500,000
500,000
22
Various ICC dockets
164,739
164,739
164,739
23
Federal Energy Regulatory Commission
24
Docket No. FA21-5-000 - FERC Audit
657,470
657,470
657,470
25
Various FERC dockets
57,307
57,307
57,307
46
TOTAL
6,028,333
6,028,333
2,160,188
9,224,259
5,128,081
2,067,098
5,221,171


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
  1. Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D and D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(Identify recipient regardless of affiliation.) For any R, D and D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts).
  2. Indicate in column (a) the applicable classification, as shown below:
    Classifications:
    1. Electric R, D and D Performed Internally:
      1. Generation
        1. hydroelectric
          1. Recreation fish and wildlife
          2. Other hydroelectric
        2. Fossil-fuel steam
        3. Internal combustion or gas turbine
        4. Nuclear
        5. Unconventional generation
        6. Siting and heat rejection
      2. Transmission
        1. Overhead
        2. Underground
      3. Distribution
      4. Regional Transmission and Market Operation
      5. Environment (other than equipment)
      6. Other (Classify and include items in excess of $50,000.)
      7. Total Cost Incurred
    2. Electric, R, D and D Performed Externally:
      1. Research Support to the electrical Research Council or the Electric Power Research Institute
      2. Research Support to Edison Electric Institute
      3. Research Support to Nuclear Power Groups
      4. Research Support to Others (Classify)
      5. Total Cost Incurred
  3. Include in column (c) all R, D and D items performed internally and in column (d) those items performed outside the company costing $50,000 or more, briefly describing the specific area of R, D and D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D and D activity.
  4. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year, listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e).
  5. Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, Development, and Demonstration Expenditures, Outstanding at the end of the year.
  6. If costs have not been segregated for R, D and D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by ""Est.""
  7. Report separately research and related testing facilities operated by the respondent.
AMOUNTS CHARGED IN CURRENT YEAR
Line No.
ResearchDevelopmentAndDemonstrationClassification
Classification
(a)
ResearchDevelopmentAndDemonstrationDescription
Description
(b)
ResearchDevelopmentAndDemonstrationCostsIncurredInternally
Costs Incurred Internally Current Year
(c)
ResearchDevelopmentAndDemonstrationCostsIncurredExternally
Costs Incurred Externally Current Year
(d)
AccountNumberForResearchDevelopmentAndDemonstrationCosts
Amounts Charged In Current Year: Account
(e)
ResearchDevelopmentAndDemonstrationCosts
Amounts Charged In Current Year: Amount
(f)
ResearchDevelopmentAndDemonstrationExpenditures
Unamortized Accumulation
(g)
1
B-1
EPRI Selected Programs
598,582
598,582
2
B-1
EPRI Selected Programs
567,084
567,084
3
B-2
CEA Technologies Inc. Program
105,881
105,881
4
B-2
CEA Technologies Inc. Program
9,786
9,786
5
B-2
National Electric Energy Testing, Research and
6
B-2
Application Center
33,416
33,416
7
B-2
Application Center
34,780
34,780
8
B-2
Watson & Renner
16,688
16,688
9
B-2
Watson & Renner
16,688
16,688
10
B-2
CIGRE
2,500
2,500
11
B-2
CIGRE
2,500
2,500
12
Total
1,387,905
1,387,905


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
DISTRIBUTION OF SALARIES AND WAGES

Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used.

Line No.
Classification
(a)
Direct Payroll Distribution
(b)
Allocation of Payroll Charged for Clearing Accounts
(c)
Total
(d)
1
SalariesAndWagesElectricAbstract
Electric
2
SalariesAndWagesElectricOperationAbstract
Operation
3
SalariesAndWagesElectricOperationProduction
Production
1,234,649
4
SalariesAndWagesElectricOperationTransmission
Transmission
27,875,117
5
SalariesAndWagesElectricOperationRegionalMarket
Regional Market
6
SalariesAndWagesElectricOperationDistribution
Distribution
67,138,139
7
SalariesAndWagesElectricOperationCustomerAccounts
Customer Accounts
103,137,544
8
SalariesAndWagesElectricOperationCustomerServiceAndInformational
Customer Service and Informational
4,219,332
9
SalariesAndWagesElectricOperationSales
Sales
10
SalariesAndWagesElectricOperationAdministrativeAndGeneral
Administrative and General
54,573,222
11
SalariesAndWagesElectricOperation
TOTAL Operation (Enter Total of lines 3 thru 10)
258,178,003
12
SalariesAndWagesElectricMaintenanceAbstract
Maintenance
13
SalariesAndWagesElectricMaintenanceProduction
Production
14
SalariesAndWagesElectricMaintenanceTransmission
Transmission
23,153,242
15
SalariesAndWagesElectricMaintenanceRegionalMarket
Regional Market
16
SalariesAndWagesElectricMaintenanceDistribution
Distribution
96,515,666
17
SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral
Administrative and General
3,645,985
18
SalariesAndWagesElectricMaintenance
TOTAL Maintenance (Total of lines 13 thru 17)
123,314,893
19
SalariesAndWagesElectricOperationAndMaintenanceAbstract
Total Operation and Maintenance
20
SalariesAndWagesElectricProduction
Production (Enter Total of lines 3 and 13)
1,234,649
21
SalariesAndWagesElectricTransmission
Transmission (Enter Total of lines 4 and 14)
51,028,359
22
SalariesAndWagesElectricRegionalMarket
Regional Market (Enter Total of Lines 5 and 15)
23
SalariesAndWagesElectricDistribution
Distribution (Enter Total of lines 6 and 16)
163,653,805
24
SalariesAndWagesElectricCustomerAccounts
Customer Accounts (Transcribe from line 7)
103,137,544
25
SalariesAndWagesElectricCustomerServiceAndInformational
Customer Service and Informational (Transcribe from line 8)
4,219,332
26
SalariesAndWagesElectricSales
Sales (Transcribe from line 9)
27
SalariesAndWagesElectricAdministrativeAndGeneral
Administrative and General (Enter Total of lines 10 and 17)
58,219,207
28
SalariesAndWagesElectricOperationAndMaintenance
TOTAL Oper. and Maint. (Total of lines 20 thru 27)
381,492,896
45,237,606
426,730,502
29
SalariesAndWagesGasAbstract
Gas
30
SalariesAndWagesGasOperationAbstract
Operation
31
SalariesAndWagesGasOperationProductionManufacturedGas
Production - Manufactured Gas
32
SalariesAndWagesGasOperationProductionNaturalGas
Production-Nat. Gas (Including Expl. And Dev.)
33
SalariesAndWagesGasOperationOtherGasSupply
Other Gas Supply
34
SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing
Storage, LNG Terminaling and Processing
35
SalariesAndWagesGasOperationTransmission
Transmission
36
SalariesAndWagesGasOperationDistribution
Distribution
37
SalariesAndWagesGasCustomerAccounts
Customer Accounts
38
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational
39
SalariesAndWagesGasSales
Sales
40
SalariesAndWagesGasOperationAdministrativeAndGeneral
Administrative and General
41
SalariesAndWagesGasOperation
TOTAL Operation (Enter Total of lines 31 thru 40)
42
SalariesAndWagesGasMaintenanceAbstract
Maintenance
43
SalariesAndWagesGasMaintenanceProductionManufacturedGas
Production - Manufactured Gas
44
SalariesAndWagesGasMaintenanceProductionNaturalGas
Production-Natural Gas (Including Exploration and Development)
45
SalariesAndWagesGasMaintenanceOtherGasSupply
Other Gas Supply
46
SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing
Storage, LNG Terminaling and Processing
47
SalariesAndWagesGasMaintenanceTransmission
Transmission
48
SalariesAndWagesGasMaintenanceDistribution
Distribution
49
SalariesAndWagesGasMaintenanceAdministrativeAndGeneral
Administrative and General
50
SalariesAndWagesGasMaintenance
TOTAL Maint. (Enter Total of lines 43 thru 49)
51
SalariesAndWagesGasOperationAndMaintenanceAbstract
Total Operation and Maintenance
52
SalariesAndWagesGasProductionManufacturedGas
Production-Manufactured Gas (Enter Total of lines 31 and 43)
53
SalariesAndWagesGasProductionNaturalGas
Production-Natural Gas (Including Expl. and Dev.) (Total lines 32,
54
SalariesAndWagesGasOtherGasSupply
Other Gas Supply (Enter Total of lines 33 and 45)
55
SalariesAndWagesGasStorageLngTerminalingAndProcessing
Storage, LNG Terminaling and Processing (Total of lines 31 thru
56
SalariesAndWagesGasTransmission
Transmission (Lines 35 and 47)
57
SalariesAndWagesGasDistribution
Distribution (Lines 36 and 48)
58
SalariesAndWagesGasCustomerAccounts
Customer Accounts (Line 37)
59
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational (Line 38)
60
SalariesAndWagesGasSales
Sales (Line 39)
61
SalariesAndWagesGasAdministrativeAndGeneral
Administrative and General (Lines 40 and 49)
62
SalariesAndWagesGasOperationAndMaintenance
TOTAL Operation and Maint. (Total of lines 52 thru 61)
63
SalariesAndWagesOtherUtilityDepartmentsAbstract
Other Utility Departments
64
SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance
Operation and Maintenance
65
SalariesAndWagesOperationsAndMaintenance
TOTAL All Utility Dept. (Total of lines 28, 62, and 64)
381,492,896
45,237,606
426,730,502
66
SalariesAndWagesUtilityPlantAbstract
Utility Plant
67
SalariesAndWagesUtilityPlantConstructionAbstract
Construction (By Utility Departments)
68
SalariesAndWagesUtilityPlantConstructionElectricPlant
Electric Plant
409,163,958
211,677,087
620,841,045
69
SalariesAndWagesUtilityPlantConstructionGasPlant
Gas Plant
70
SalariesAndWagesUtilityPlantConstructionOther
Other (provide details in footnote):
71
SalariesAndWagesUtilityPlantConstruction
TOTAL Construction (Total of lines 68 thru 70)
409,163,958
211,677,087
620,841,045
72
SalariesAndWagesPlantRemovalAbstract
Plant Removal (By Utility Departments)
73
SalariesAndWagesPlantRemovalElectricPlant
Electric Plant
45,174,325
20,277,200
65,451,525
74
SalariesAndWagesPlantRemovalGasPlant
Gas Plant
75
SalariesAndWagesPlantRemovalOther
Other (provide details in footnote):
76
SalariesAndWagesPlantRemoval
TOTAL Plant Removal (Total of lines 73 thru 75)
45,174,325
20,277,200
65,451,525
77
SalariesAndWagesOtherAccountsAbstract
Other Accounts (Specify, provide details in footnote):
78
SalariesAndWagesOtherAccountsDescription
Other Accounts (Specify, provide details in footnote):
79
SalariesAndWagesOtherAccountsDescription
Stores Expense Undistributed
21,569,489
21,569,489
80
SalariesAndWagesOtherAccountsDescription
Clearing Accounts
77,434,410
77,434,410
81
SalariesAndWagesOtherAccountsDescription
Miscellaneous
(a)
21,057,027
21,057,027
82
SalariesAndWagesOtherAccountsDescription
83
SalariesAndWagesOtherAccountsDescription
84
SalariesAndWagesOtherAccountsDescription
85
SalariesAndWagesOtherAccountsDescription
86
SalariesAndWagesOtherAccountsDescription
87
SalariesAndWagesOtherAccountsDescription
88
SalariesAndWagesOtherAccountsDescription
89
SalariesAndWagesOtherAccountsDescription
90
SalariesAndWagesOtherAccountsDescription
91
SalariesAndWagesOtherAccountsDescription
92
SalariesAndWagesOtherAccountsDescription
93
SalariesAndWagesOtherAccountsDescription
94
SalariesAndWagesOtherAccountsDescription
95
SalariesAndWagesOtherAccounts
TOTAL Other Accounts
120,060,926
99,003,899
21,057,027
96
SalariesAndWagesGeneralExpense
TOTAL SALARIES AND WAGES
955,892,105
178,187,994
1,134,080,099


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: SalariesAndWagesOtherAccounts
Includes direct labor charges related to non-utility operations.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
COMMON UTILITY PLANT AND EXPENSES
  1. Describe the property carried in the utility's accounts as common utility plant and show the book cost of such plant at end of year classified by accounts as provided by Electric Plant Instruction 13, Common Utility Plant, of the Uniform System of Accounts. Also show the allocation of such plant costs to the respective departments using the common utility plant and explain the basis of allocation used, giving the allocation factors.
  2. Furnish the accumulated provisions for depreciation and amortization at end of year, showing the amounts and classifications of such accumulated provisions, and amounts allocated to utility departments using the common utility plant to which such accumulated provisions relate, including explanation of basis of allocation and factors used.
  3. Give for the year the expenses of operation, maintenance, rents, depreciation, and amortization for common utility plant classified by accounts as provided by the Uniform System of Accounts. Show the allocation of such expenses to the departments using the common utility plant to which such expenses are related. Explain the basis of allocation used and give the factors of allocation.
  4. Give date of approval by the Commission for use of the common utility plant classification and reference to the order of the Commission or other authorization.


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
  1. The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No.
Description of Item(s)
(a)
Balance at End of Quarter 1
(b)
Balance at End of Quarter 2
(c)
Balance at End of Quarter 3
(d)
Balance at End of Year
(e)
1 Energy
2 Net Purchases (Account 555)
127,214,630
268,625,245
531,499,783
(a)
691,537,366
2.1 Net Purchases (Account 555.1)
3 Net Sales (Account 447)
5,105,563
8,876,943
22,944,367
27,394,838
4 Transmission Rights
5 Ancillary Services
6,933,165
16,209,887
27,796,060
(b)
38,170,444
6 Other Items (list separately)
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46 TOTAL
139,253,358
293,712,075
582,240,210
757,102,648


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: IsoOrRtoSettlementsEnergyNetPurchasesPurchasedPower
Amounts reported in Line Nos. 2, 3 & 5 reflect the year-to-date activities through the end of the applicable quarter.
(b) Concept: IsoOrRtoSettlementsAncillaryServices
Purchases and sales of ancillary services were recorded in the following accounts:
Purchases
Account 555 $ 38,534,112 
Account 561.4 14,332,388 
Account 561.8 684,154 
Account 575.7 6,841,513 
Sales
Account 456.1 (22,221,723)
Total $ 38,170,444 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
PURCHASES AND SALES OF ANCILLARY SERVICES
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff.
In columns for usage, report usage-related billing determinant and the unit of measure.
  1. On Line 1 columns (b), (c), (d), and (e) report the amount of ancillary services purchased and sold during the year.
  2. On Line 2 columns (b), (c), (d), and (e) report the amount of reactive supply and voltage control services purchased and sold during the year.
  3. On Line 3 columns (b), (c), (d), and (e) report the amount of regulation and frequency response services purchased and sold during the year.
  4. On Line 4 columns (b), (c), (d), and (e) report the amount of energy imbalance services purchased and sold during the year.
  5. On Lines 5 and 6, columns (b), (c), (d), and (e) report the amount of operating reserve spinning and supplement services purchased and sold during the period.
  6. On Line 7 columns (b), (c), (d), and (e) report the total amount of all other types ancillary services purchased or sold during the year. Include in a footnote and specify the amount for each type of other ancillary service provided.
Amount Purchased for the Year Amount Sold for the Year
Usage - Related Billing Determinant Usage - Related Billing Determinant
Line No.
Type of Ancillary Service
(a)
Number of Units
(b)
Unit of Measure
(c)
Dollar
(d)
Number of Units
(e)
Unit of Measure
(f)
Dollars
(g)
1
Scheduling, System Control and Dispatch
32,176,037
MWH
20,309,969
91,236,639
MWH
(a)
22,221,723
2
Reactive Supply and Voltage
(b)
23,325,901
3
Regulation and Frequency Response
(c)
5,371,217
4
Energy Imbalance
5
Operating Reserve - Spinning
(d)
2,761,637
6
Operating Reserve - Supplement
(e)
2,962,446
7
Other
(f)
5,660,997
8
Total (Lines 1 thru 7)
32,176,037
60,392,167
91,236,639
22,221,723


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: AncillaryServicesSoldAmount
Represents revenues allocated to the respondent from PJM Interconnection, LLC.
(b) Concept: AncillaryServicesPurchasedAmount
Represents the per load ratio share.
(c) Concept: AncillaryServicesPurchasedAmount
This footnote applies to the cells in lines 3, 5, and 6, column d. The number of units applicable to Line No. 3, Column (b) is 32,176,037.
(d) Concept: AncillaryServicesPurchasedAmount
This footnote applies to the cells in lines 3, 5, and 6, column d. The number of units applicable to Line No. 3, Column (b) is 32,176,037.
(e) Concept: AncillaryServicesPurchasedAmount
This footnote applies to the cells in lines 3, 5, and 6, column d. The number of units applicable to Line No. 3, Column (b) is 32,176,037.
(f) Concept: AncillaryServicesPurchasedAmount
The details of this "Other" amount are as follows:
Black Start service charge $ 4,171,292 
Schedule 10 - NERC charges 620,322 
Schedule 10 - RFC charges 896,247 
Reconciliation of Schedule 10 charges 12,387 
Consumer Advocates of PJM States, Inc. (CAPS) 19,130 
Fuel Cost Policy Penalty (58,381)
$ 5,660,997 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
MONTHLY TRANSMISSION SYSTEM PEAK LOAD
  1. Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system.
  2. Report on Column (b) by month the transmission system's peak load.
  3. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).
  4. Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No.
Month
(a)
Monthly Peak MW - Total
(b)
Day of Monthly Peak
(c)
Hour of Monthly Peak
(d)
Firm Network Service for Self
(e)
Firm Network Service for Others
(f)
Long-Term Firm Point-to-point Reservations
(g)
Other Long-Term Firm Service
(h)
Short-Term Firm Point-to-point Reservation
(i)
Other Service
(j)
NAME OF SYSTEM: 0
1
January
13,658
31
(a)
18
5,464
8,194
2
February
13,392
3
(b)
18
5,329
8,063
3
March
11,931
14
4,094
7,837
4
Total for Quarter 1
14,887
24,094
0
0
0
0
5
April
11,698
13
(d)
17
4,129
7,569
6
May
15,598
31
(e)
13
6,122
9,476
7
June
16,786
30
(f)
13
7,059
9,727
8
Total for Quarter 2
17,310
26,772
0
0
0
0
9
July
19,358
27
(g)
16
8,975
10,383
10
August
22,467
24
(h)
16
10,786
11,681
11
September
18,322
5
(i)
13
7,775
10,547
12
Total for Quarter 3
27,536
32,611
0
0
0
0
13
October
14,968
3
(j)
16
5,979
8,989
14
November
13,096
28
(k)
17
4,985
8,111
15
December
12,949
18
(l)
17
4,888
8,061
16
Total for Quarter 4
15,852
25,161
0
0
0
0
17
Total
75,585
108,638
0
0
0
0


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: HourOfMonthlyPeakExcludingIsoAndRto
Hours reported in Column (d) are presented in Central Standard Time (CST) since ComEd Operations are in that time zone.
(b) Concept: HourOfMonthlyPeakExcludingIsoAndRto
Hours reported in Column (d) are presented in Central Standard Time (CST) since ComEd Operations are in that time zone.
(c) Concept: HourOfMonthlyPeakExcludingIsoAndRto
Hours reported in Column (d) are presented in Central Standard Time (CST) since ComEd Operations are in that time zone.
(d) Concept: HourOfMonthlyPeakExcludingIsoAndRto
Hours reported in Column (d) are presented in Central Standard Time (CST) since ComEd Operations are in that time zone.
(e) Concept: HourOfMonthlyPeakExcludingIsoAndRto
Hours reported in Column (d) are presented in Central Standard Time (CST) since ComEd Operations are in that time zone.
(f) Concept: HourOfMonthlyPeakExcludingIsoAndRto
Hours reported in Column (d) are presented in Central Standard Time (CST) since ComEd Operations are in that time zone.
(g) Concept: HourOfMonthlyPeakExcludingIsoAndRto
Hours reported in Column (d) are presented in Central Standard Time (CST) since ComEd Operations are in that time zone.
(h) Concept: HourOfMonthlyPeakExcludingIsoAndRto
Hours reported in Column (d) are presented in Central Standard Time (CST) since ComEd Operations are in that time zone.
(i) Concept: HourOfMonthlyPeakExcludingIsoAndRto
Hours reported in Column (d) are presented in Central Standard Time (CST) since ComEd Operations are in that time zone.
(j) Concept: HourOfMonthlyPeakExcludingIsoAndRto
Hours reported in Column (d) are presented in Central Standard Time (CST) since ComEd Operations are in that time zone.
(k) Concept: HourOfMonthlyPeakExcludingIsoAndRto
Hours reported in Column (d) are presented in Central Standard Time (CST) since ComEd Operations are in that time zone.
(l) Concept: HourOfMonthlyPeakExcludingIsoAndRto
Hours reported in Column (d) are presented in Central Standard Time (CST) since ComEd Operations are in that time zone.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
Monthly ISO/RTO Transmission System Peak Load
  1. Report the monthly peak load on the respondent's transmission system. If the Respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system.
  2. Report on Column (b) by month the transmission system's peak load.
  3. Report on Column (c) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).
  4. Report on Columns (e) through (i) by month the system’s transmission usage by classification. Amounts reported as Through and Out Service in Column (g) are to be excluded from those amounts reported in Columns (e) and (f).
  5. Amounts reported in Column (j) for Total Usage is the sum of Columns (h) and (i).
Line No.
Month
(a)
Monthly Peak MW - Total
(b)
Day of Monthly Peak
(c)
Hour of Monthly Peak
(d)
Import into ISO/RTO
(e)
Exports from ISO/RTO
(f)
Through and Out Service
(g)
Network Service Usage
(h)
Point-to-Point Service Usage
(i)
Total Usage
(j)
NAME OF SYSTEM: 0
1
January
2
February
3
March
4
Total for Quarter 1
0
0
0
0
0
0
5
April
6
May
7
June
8
Total for Quarter 2
0
0
0
0
0
0
9
July
10
August
11
September
12
Total for Quarter 3
0
0
0
0
0
0
13
October
14
November
15
December
16
Total for Quarter 4
0
0
0
0
0
0
17
Total Year to Date/Year
0
0
0
0
0
0


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2023-12-31
Year/Period of Report

End of:
2023
/
Q4
ELECTRIC ENERGY ACCOUNT

Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year.

Line No. Item
(a)
MegaWatt Hours
(b)
Line No. Item
(a)
MegaWatt Hours
(b)
1
SOURCES OF ENERGY
21
DISPOSITION OF ENERGY
2
Generation (Excluding Station Use):
22
Sales to Ultimate Consumers (Including Interdepartmental Sales)
(a)(b)
82,290,221
3
Steam
23
Requirements Sales for Resale (See instruction 4, page 311.)
4
Nuclear
24
Non-Requirements Sales for Resale (See instruction 4, page 311.)
988,910
5
Hydro-Conventional
25
Energy Furnished Without Charge
389,385
6
Hydro-Pumped Storage
26
Energy Used by the Company (Electric Dept Only, Excluding Station Use)
7
Other
27
Total Energy Losses
5,906,237
8
Less Energy for Pumping
27.1
Total Energy Stored
9
Net Generation (Enter Total of lines 3 through 8)
0
28
TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES
89,574,753
10
Purchases (other than for Energy Storage)
(c)
32,969,470
10.1
Purchases for Energy Storage
0
11
Power Exchanges:
12
Received
0
13
Delivered
0
14
Net Exchanges (Line 12 minus line 13)
0
15
Transmission For Other (Wheeling)
16
Received
56,605,283
17
Delivered
18
Net Transmission for Other (Line 16 minus line 17)
56,605,283
19
Transmission By Others Losses
20
TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19)
89,574,753


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2023-12-31
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: MegawattHoursSoldSalesToUltimateConsumers
MWh's for the Years Ended December 31,
2023 2022
Retail deliveries for Full Service
$ 29,964,172  $ 31,414,991 
Retail deliveries for Delivery Only
52,326,049 53,984,286
Total retail deliveries
$ 82,290,221  $ 85,399,277 
General Notes:
Full Service reflects deliveries to customers taking electric service under tariff rates. Delivery Only service reflects customers electing to receive electricity from Alternative Retail Electric Suppliers.
(b) Concept: MegawattHoursSoldSalesToUltimateConsumers
Retail deliveries for Full Service $ 29,964,172 
Retail deliveries for Delivery Only 52,326,049 
Total Sales to Ultimate Customers $ 82,290,221 
Refer to the footnote on Page 300, line No. 10, Column (d) for additional details.
(c) Concept: MegawattHoursPurchasedOtherThanStorage
Reflects utility zone load, which includes the following amounts purchased by ComEd to serve its Full Service customers.
1Q 2023 Month MWhs
January 2,869,396 
February 2,610,865 
March 2,657,711 
Quarter Total 8,137,972 
2Q 2023 Month MWhs
April 2,177,825 
May 2,276,382 
June 2,770,877 
Quarter Total 7,225,084 
3Q 2023 Month MWhs
July 3,617,373 
August 3,868,648 
September 3,161,863 
Quarter Total 10,647,884 
4Q 2023 Month MWhs
October 1,946,443 
November 2,363,638 
December 2,648,449 
Quarter Total 6,958,530 
YTD Total 32,969,470 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
MONTHLY PEAKS AND OUTPUT
  1. Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system.
  2. Report in column (b) by month the system’s output in Megawatt hours for each month.
  3. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales.
  4. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system.
  5. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).
Line No.
MonthAxis
Month
(a)
EnergyActivity
Total Monthly Energy
(b)
NonRequiredSalesForResaleEnergy
Monthly Non-Requirement Sales for Resale & Associated Losses
(c)
MonthlyPeakLoad
Monthly Peak - Megawatts
(d)
DayOfMonthlyPeak
Monthly Peak - Day of Month
(e)
HourOfMonthlyPeak
Monthly Peak - Hour
(f)
NAME OF SYSTEM: 0
29
January
7,781,274
57,819
13,658
31
(a)
18
30
February
6,955,830
93,106
13,392
3
(b)
18
31
March
7,314,786
48,391
11,931
14
32
April
6,479,301
28,035
11,698
13
(d)
17
33
May
6,819,069
51,810
15,598
31
(e)
13
34
June
7,700,103
89,249
16,786
30
(f)
13
35
July
9,007,596
150,023
19,358
27
(g)
16
36
August
8,957,831
157,155
22,467
24
(h)
16
37
September
7,345,398
136,129
18,322
5
(i)
13
38
October
6,969,662
57,678
14,968
3
(j)
16
39
November
6,871,599
65,779
13,096
23
(k)
17
40
December
7,372,304
53,736
12,949
18
(l)
17
41
Total
89,574,753
988,910


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: HourOfMonthlyPeak
Hours reported in Column (f) are presented in the Central Standard Time (CST) since ComEd operations are in that time zone.
(b) Concept: HourOfMonthlyPeak
Hours reported in Column (f) are presented in the Central Standard Time (CST) since ComEd operations are in that time zone.
(c) Concept: HourOfMonthlyPeak
Hours reported in Column (f) are presented in the Central Standard Time (CST) since ComEd operations are in that time zone.
(d) Concept: HourOfMonthlyPeak
Hours reported in Column (f) are presented in the Central Standard Time (CST) since ComEd operations are in that time zone.
(e) Concept: HourOfMonthlyPeak
Hours reported in Column (f) are presented in the Central Standard Time (CST) since ComEd operations are in that time zone.
(f) Concept: HourOfMonthlyPeak
Hours reported in Column (f) are presented in the Central Standard Time (CST) since ComEd operations are in that time zone.
(g) Concept: HourOfMonthlyPeak
Hours reported in Column (f) are presented in the Central Standard Time (CST) since ComEd operations are in that time zone.
(h) Concept: HourOfMonthlyPeak
Hours reported in Column (f) are presented in the Central Standard Time (CST) since ComEd operations are in that time zone.
(i) Concept: HourOfMonthlyPeak
Hours reported in Column (f) are presented in the Central Standard Time (CST) since ComEd operations are in that time zone.
(j) Concept: HourOfMonthlyPeak
Hours reported in Column (f) are presented in the Central Standard Time (CST) since ComEd operations are in that time zone.
(k) Concept: HourOfMonthlyPeak
Hours reported in Column (f) are presented in the Central Standard Time (CST) since ComEd operations are in that time zone.
(l) Concept: HourOfMonthlyPeak
Hours reported in Column (f) are presented in the Central Standard Time (CST) since ComEd operations are in that time zone.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
Steam Electric Generating Plant Statistics

1. Report data for plant in Service only.
2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants.
3. Indicate by a footnote any plant leased or operated as a joint facility.
4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.
5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.
6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mcf.
7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20.
8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned.
9. Items under Cost of Plant are based on USofA accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.
10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.
11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.
12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant.

Line No.
Item
(a)
Plant Name:
0
1
PlantKind
Kind of Plant (Internal Comb, Gas Turb, Nuclear)
2
PlantConstructionType
Type of Constr (Conventional, Outdoor, Boiler, etc)
3
YearPlantOriginallyConstructed
Year Originally Constructed
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
5
InstalledCapacityOfPlant
Total Installed Cap (Max Gen Name Plate Ratings-MW)
6
NetPeakDemandOnPlant
Net Peak Demand on Plant - MW (60 minutes)
7
PlantHoursConnectedToLoad
Plant Hours Connected to Load
8
NetContinuousPlantCapability
Net Continuous Plant Capability (Megawatts)
9
NetContinuousPlantCapabilityNotLimitedByCondenserWater
When Not Limited by Condenser Water
10
NetContinuousPlantCapabilityLimitedByCondenserWater
When Limited by Condenser Water
11
PlantAverageNumberOfEmployees
Average Number of Employees
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - kWh
13
CostOfLandAndLandRightsSteamProduction
Cost of Plant: Land and Land Rights
14
CostOfStructuresAndImprovementsSteamProduction
Structures and Improvements
15
CostOfEquipmentSteamProduction
Equipment Costs
16
AssetRetirementCostsSteamProduction
Asset Retirement Costs
17
CostOfPlant
Total cost (total 13 thru 20)
18
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 17/5) Including
19
OperationSupervisionAndEngineeringExpense
Production Expenses: Oper, Supv, & Engr
20
FuelSteamPowerGeneration
Fuel
21
CoolantsAndWater
Coolants and Water (Nuclear Plants Only)
22
SteamExpensesSteamPowerGeneration
Steam Expenses
23
SteamFromOtherSources
Steam From Other Sources
24
SteamTransferredCredit
Steam Transferred (Cr)
25
ElectricExpensesSteamPowerGeneration
Electric Expenses
26
MiscellaneousSteamPowerExpenses
Misc Steam (or Nuclear) Power Expenses
27
RentsSteamPowerGeneration
Rents
28
Allowances
Allowances
29
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
Maintenance Supervision and Engineering
30
MaintenanceOfStructuresSteamPowerGeneration
Maintenance of Structures
31
MaintenanceOfBoilerPlantSteamPowerGeneration
Maintenance of Boiler (or reactor) Plant
32
MaintenanceOfElectricPlantSteamPowerGeneration
Maintenance of Electric Plant
33
MaintenanceOfMiscellaneousSteamPlant
Maintenance of Misc Steam (or Nuclear) Plant
34
PowerProductionExpensesSteamPower
Total Production Expenses
0
35
ExpensesPerNetKilowattHour
Expenses per Net kWh
35
FuelKindAxis
Plant Name
36
FuelKind
Fuel Kind
37
FuelUnit
Fuel Unit
38
QuantityOfFuelBurned
Quantity (Units) of Fuel Burned
39
FuelBurnedAverageHeatContent
Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)
40
AverageCostOfFuelPerUnitAsDelivered
Avg Cost of Fuel/unit, as Delvd f.o.b. during year
41
AverageCostOfFuelPerUnitBurned
Average Cost of Fuel per Unit Burned
42
AverageCostOfFuelBurnedPerMillionBritishThermalUnit
Average Cost of Fuel Burned per Million BTU
43
AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Average Cost of Fuel Burned per kWh Net Gen
44
AverageBritishThermalUnitPerKilowattHourNetGeneration
Average BTU per kWh Net Generation


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
Hydroelectric Generating Plant Statistics
  1. Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings).
  2. If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number.
  3. If net peak demand for 60 minutes is not available, give that which is available specifying period.
  4. If a group of employees attends more than one generating plant, report on line 11 the approximate average number of employees assignable to each plant.
  5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
  6. Report as a separate plant any plant equipped with combinations of steam, hydro, internal combustion engine, or gas turbine equipment.
Line No.
Item
(a)
FERC Licensed Project No.
0
Plant Name:
0
1
PlantKind
Kind of Plant (Run-of-River or Storage)
2
PlantConstructionType
Plant Construction type (Conventional or Outdoor)
3
YearPlantOriginallyConstructed
Year Originally Constructed
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
5
InstalledCapacityOfPlant
Total installed cap (Gen name plate Rating in MW)
6
NetPeakDemandOnPlant
Net Peak Demand on Plant-Megawatts (60 minutes)
7
PlantHoursConnectedToLoad
Plant Hours Connect to Load
8
NetPlantCapabilityAbstract
Net Plant Capability (in megawatts)
9
NetPlantCapabilityUnderMostFavorableOperatingConditions
(a) Under Most Favorable Oper Conditions
10
NetPlantCapabilityUnderMostAdverseOperatingConditions
(b) Under the Most Adverse Oper Conditions
11
PlantAverageNumberOfEmployees
Average Number of Employees
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - kWh
13
CostOfPlantAbstract
Cost of Plant
14
CostOfLandAndLandRightsHydroelectricProduction
Land and Land Rights
15
CostOfStructuresAndImprovementsHydroelectricProduction
Structures and Improvements
16
CostOfReservoirsDamsAndWaterwaysHydroelectricProduction
Reservoirs, Dams, and Waterways
17
EquipmentCostsHydroelectricProduction
Equipment Costs
18
CostOfRoadsRailroadsAndBridgesHydroelectricProduction
Roads, Railroads, and Bridges
19
AssetRetirementCostsHydroelectricProduction
Asset Retirement Costs
20
CostOfPlant
Total cost (total 13 thru 20)
21
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 20 / 5)
22
ProductionExpensesAbstract
Production Expenses
23
OperationSupervisionAndEngineeringExpense
Operation Supervision and Engineering
24
WaterForPower
Water for Power
25
HydraulicExpenses
Hydraulic Expenses
26
ElectricExpensesHydraulicPowerGeneration
Electric Expenses
27
MiscellaneousHydraulicPowerGenerationExpenses
Misc Hydraulic Power Generation Expenses
28
RentsHydraulicPowerGeneration
Rents
29
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
Maintenance Supervision and Engineering
30
MaintenanceOfStructuresHydraulicPowerGeneration
Maintenance of Structures
31
MaintenanceOfReservoirsDamsAndWaterways
Maintenance of Reservoirs, Dams, and Waterways
32
MaintenanceOfElectricPlantHydraulicPowerGeneration
Maintenance of Electric Plant
33
MaintenanceOfMiscellaneousHydraulicPlant
Maintenance of Misc Hydraulic Plant
34
PowerProductionExpensesHydraulicPower
Total Production Expenses (total 23 thru 33)
35
ExpensesPerNetKilowattHour
Expenses per net kWh


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
Pumped Storage Generating Plant Statistics
  1. Large plants and pumped storage plants of 10,000 Kw or more of installed capacity (name plate ratings).
  2. If any plant is leased, operating under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. Give project number.
  3. If net peak demand for 60 minutes is not available, give that which is available, specifying period.
  4. If a group of employees attends more than one generating plant, report on Line 8 the approximate average number of employees assignable to each plant.
  5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power System Control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
  6. Pumping energy (Line 10) is that energy measured as input to the plant for pumping purposes.
  7. Include on Line 36 the cost of energy used in pumping into the storage reservoir. When this item cannot be accurately computed leave Lines 36, 37 and 38 blank and describe at the bottom of the schedule the company's principal sources of pumping power, the estimated amounts of energy from each station or other source that individually provides more than 10 percent of the total energy used for pumping, and production expenses per net MWH as reported herein for each source described. Group together stations and other resources which individually provide less than 10 percent of total pumping energy. If contracts are made with others to purchase power for pumping, give the supplier contract number, and date of contract.
Line No.
Item
(a)
FERC Licensed Project No.
0
Plant Name:
0
1
PlantConstructionType
Type of Plant Construction (Conventional or Outdoor)
2
YearPlantOriginallyConstructed
Year Originally Constructed
3
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
4
InstalledCapacityOfPlant
Total installed cap (Gen name plate Rating in MW)
5
NetPeakDemandOnPlant
Net Peak Demaind on Plant-Megawatts (60 minutes)
0
6
PlantHoursConnectedToLoad
Plant Hours Connect to Load While Generating
0
7
NetContinuousPlantCapability
Net Plant Capability (in megawatts)
0
8
PlantAverageNumberOfEmployees
Average Number of Employees
9
NetGenerationExcludingPlantUse
Generation, Exclusive of Plant Use - kWh
0
10
EnergyUsedForPumping
Energy Used for Pumping
11
NetOutputForLoad
Net Output for Load (line 9 - line 10) - Kwh
0
12
CostOfPlantAbstract
Cost of Plant
13
CostOfLandAndLandRightsPumpedStoragePlant
Land and Land Rights
14
CostOfStructuresAndImprovementsPumpedStoragePlant
Structures and Improvements
0
15
CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant
Reservoirs, Dams, and Waterways
0
16
CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant
Water Wheels, Turbines, and Generators
0
17
CostOfAccessoryElectricEquipmentPumpedStoragePlant
Accessory Electric Equipment
0
18
CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant
Miscellaneous Powerplant Equipment
0
19
CostOfRoadsRailroadsAndBridgesPumpedStoragePlant
Roads, Railroads, and Bridges
0
20
AssetRetirementCostsPumpedStoragePlant
Asset Retirement Costs
0
21
CostOfPlant
Total cost (total 13 thru 20)
22
CostPerKilowattOfInstalledCapacity
Cost per KW of installed cap (line 21 / 4)
23
ProductionExpensesAbstract
Production Expenses
24
OperationSupervisionAndEngineeringExpense
Operation Supervision and Engineering
0
25
WaterForPower
Water for Power
0
26
PumpedStorageExpenses
Pumped Storage Expenses
0
27
ElectricExpensesPumpedStoragePlant
Electric Expenses
0
28
MiscellaneousPumpedStoragePowerGenerationExpenses
Misc Pumped Storage Power generation Expenses
0
29
RentsPumpedStoragePlant
Rents
0
30
MaintenanceSupervisionAndEngineeringPumpedStoragePlant
Maintenance Supervision and Engineering
0
31
MaintenanceOfStructuresPumpedStoragePlant
Maintenance of Structures
0
32
MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant
Maintenance of Reservoirs, Dams, and Waterways
0
33
MaintenanceOfElectricPlantPumpedStoragePlant
Maintenance of Electric Plant
0
34
MaintenanceOfMiscellaneousPumpedStoragePlant
Maintenance of Misc Pumped Storage Plant
0
35
PowerProductionExpenseBeforePumpingExpenses
Production Exp Before Pumping Exp (24 thru 34)
36
PumpingExpenses
Pumping Expenses
37
PowerProductionExpensesPumpedStoragePlant
Total Production Exp (total 35 and 36)
38
ExpensesPerNetKilowattHour
Expenses per kWh (line 37 / 9)
39
ExpensesPerNetKilowattHourGenerationAndPumping
Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10))
0


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
GENERATING PLANT STATISTICS (Small Plants)
  1. Small generating plants are steam plants of, less than 25,000 Kw; internal combustion and gas turbine-plants, conventional hydro plants and pumped storage plants of less than 10,000 Kw installed capacity (name plate rating).
  2. Designate any plant leased from others, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, and give a concise statement of the facts in a footnote. If licensed project, give project number in footnote.
  3. List plants appropriately under subheadings for steam, hydro, nuclear, internal combustion and gas turbine plants. For nuclear, see instruction 11, Page 402.
  4. If net peak demand for 60 minutes is not available, give the which is available, specifying period.
  5. If any plant is equipped with combinations of steam, hydro internal combustion or gas turbine equipment, report each as a separate plant. However, if the exhaust heat from the gas turbine is utilized in a steam turbine regenerative feed water cycle, or for preheated combustion air in a boiler, report as one plant.
Production Expenses
Line No.
PlantName
Name of Plant
(a)
YearPlantOriginallyConstructed
Year Orig. Const.
(b)
InstalledCapacityOfPlant
Installed Capacity Name Plate Rating (MW)
(c)
NetPeakDemandOnPlant
Net Peak Demand MW (60 min)
(d)
NetGenerationExcludingPlantUse
Net Generation Excluding Plant Use
(e)
CostOfPlant
Cost of Plant
(f)
PlantCostPerMw
Plant Cost (Incl Asset Retire. Costs) Per MW
(g)
OperatingExpensesExcludingFuel
Operation Exc'l. Fuel
(h)
FuelProductionExpenses
Fuel Production Expenses
(i)
MaintenanceProductionExpenses
Maintenance Production Expenses
(j)
FuelKind
Kind of Fuel
(k)
FuelCostPerMmbtus
Fuel Costs (in cents (per Million Btu)
(l)
GenerationType
Generation Type
(m)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
ENERGY STORAGE OPERATIONS (Large Plants)
  1. Large Plants are plants of 10,000 Kw or more.
  2. In columns (a) (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location.
  3. In column (d), report Megawatt hours (MWH) purchased, generated, or received in exchange transactions for storage.
  4. In columns (e), (f) and (g) report MWHs delivered to the grid to support production, transmission and distribution. The amount reported in column (d) should include MWHs delivered/provided to a generator’s own load requirements or used for the provision of ancillary services.
  5. In columns (h), (i), and (j) report MWHs lost during conversion, storage and discharge of energy.
  6. In column (k) report the MWHs sold.
  7. In column (l), report revenues from energy storage operations. In a footnote, disclose the revenue accounts and revenue amounts related to the income generating activity.
  8. In column (m), report the cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. In columns (n) and (o), report fuel costs for storage operations associated with self-generated power included in Account 501 and other costs associated with self-generated power.
  9. In columns (q), (r) and (s) report the total project plant costs including but not exclusive of land and land rights, structures and improvements, energy storage equipment, turbines, compressors, generators, switching and conversion equipment, lines and equipment whose primary purpose is to integrate or tie energy storage assets into the power grid, and any other costs associated with the energy storage project included in the property accounts listed.
Line No.
Name of the Energy Storage Project
(a)
Functional Classification
(b)
Location of the Project
(c)
MWHs
(d)
MWHs delivered to the grid to support Production
(e)
MWHs delivered to the grid to support Transmission
(f)
MWHs delivered to the grid to support Distribution
(g)
MWHs Lost During Conversion, Storage and Discharge of Energy Production
(h)
MWHs Lost During Conversion, Storage and Discharge of Energy Transmission
(i)
MWHs Lost During Conversion, Storage and Discharge of Energy Distribution
(j)
MWHs Sold
(k)
Revenues from Energy Storage Operations
(l)
Power Purchased for Storage Operations (555.1) (Dollars)
(m)
Fuel Costs from associated fuel accounts for Storage Operations Associated with Self- Generated Power (Dollars)
(n)
Other Costs Associated with Self-Generated Power (Dollars)
(o)
Account for Project Costs
(p)
Production (Dollars)
(q)
Transmission (Dollars)
(r)
Distribution (Dollars)
(s)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35 TOTAL
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
ENERGY STORAGE OPERATIONS (Small Plants)
  1. Small Plants are plants less than 10,000 Kw.
  2. In columns (a), (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location.
  3. In column (d), report project plant cost including but not exclusive of land and land rights, structures and improvements, energy storage equipment and any other costs associated with the energy storage project.
  4. In column (e), report operation expenses excluding fuel, (f), maintenance expenses, (g) fuel costs for storage operations and (h) cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined.
  5. If any other expenses, report in column (i) and footnote the nature of the item(s).
BALANCE AT BEGINNING OF YEAR
Line No.
Name of the Energy Storage Project
(a)
Functional Classification
(b)
Location of the Project
(c)
Project Cost
(d)
Operations (Excluding Fuel used in Storage Operations)
(e)
Maintenance
(f)
Cost of fuel used in storage operations
(g)
Account No. 555.1, Power Purchased for Storage Operations
(h)
Other Expenses
(i)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36 TOTAL
0
0
0
0
0
0


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
TRANSMISSION LINE STATISTICS
  1. Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. If required by a State commission to report individual lines for all voltages, do so but do not group totals for each voltage under 132 kilovolts.
  2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page.
  3. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property.
  4. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line.
  5. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated.
  6. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g).
  7. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company.
  8. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company.
  9. Base the plant cost figures called for in columns (j) to (l) on the book cost at end of year.
DESIGNATION VOLTAGE (KV) - (Indicate where other than 60 cycle, 3 phase) LENGTH (Pole miles) - (In the case of underground lines report circuit miles) COST OF LINE (Include in column (j) Land, Land rights, and clearing right-of-way) EXPENSES, EXCEPT DEPRECIATION AND TAXES
Line No.
TransmissionLineStartPoint
From
TransmissionLineEndPoint
To
OperatingVoltageOfTransmissionLine
Operating
DesignedVoltageOfTransmissionLine
Designated
SupportingStructureOfTransmissionLineType
Type of Supporting Structure
LengthForStandAloneTransmissionLines
On Structure of Line Designated
LengthForTransmissionLinesAggregatedWithOtherStructures
On Structures of Another Line
NumberOfTransmissionCircuits
Number of Circuits
SizeOfConductorAndMaterial
Size of Conductor and Material
CostOfLandAndLandRightsTransmissionLines
Land
ConstructionAndOtherCostsTransmissionLines
Construction Costs
OverallCostOfTransmissionLine
Total Costs
OperatingExpensesOfTransmissionLine
Operation Expenses
MaintenanceExpensesOfTransmissionLine
Maintenance Expenses
RentExpensesOfTransmissionLine
Rents
OverallExpensesOfTransmissionLine
Total Expenses
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
(k)
(l)
(m)
(n)
(o)
(p)
1
(a)
138 KV Line
30,412,187
1,313,926,268
1,344,338,455
2
345 KV Line
91,507,142
1,377,643,863
1,469,151,005
3
765 KV Line
9,668,733
49,713,155
59,381,888
4
Overhead Line Expenses
5
Underground Line Expenses
6
765KV LINES OVERHEAD
7
2315 COLLINS
PLANO
765
765
34.41
1
4-1585 AE ACAR
8
11215 WILTON CENTER
ILL-IND STATE LINE
765
765
27.82
1
4-1277 ACAR
9
11216 WILTON CENTER
COLLINS
765
765
27.37
1
4-1585 AE ACAR
10
345KV LINES OVERHEAD
345kV LINES
11
0101 LASALLE - 1
PLANO
345
345
28.64
1
2-1277 ACAR
12
0101 LASALLE - 2
PLANO
345
345
12.32
2-1277 ACAR
13
0102 LASALLE - 1
PLANO
345
345
0.47
28.14
1
2-1277 ACAR
14
0102 LASALLE - 2
PLANO
345
345
12.32
2-1277 ACAR, 2-T2-1192 AAC
15
0103 LASALLE - 1
BRAIDWOOD
345
345
24.86
1
2-1277 ACAR
16
0103 LASALLE - 2
BRAIDWOOD
345
345
0.69
2-1277 ACAR
17
0104 LASALLE - 1
BRAIDWOOD
345
345
0.58
1
2-1277 ACAR
18
0104 LASALLE - 2
BRAIDWOOD
345
345
24.86
2-1277 ACAR
19
0301 POWERTON - 1
KATYDID
345
345
1.89
1
2-1277 ACAR
20
0301 POWERTON - 2
KATYDID
345
345
72.02
2-1277 ACAR
21
0302 POWERTON - 1
MOLE CREEK
345
345
1.37
1
2-1277 ACAR
22
0302 POWERTON - 2
MOLE CREEK
345
345
44.81
2-1277 ACAR
23
0303 POWERTON - 1
NEVADA
345
345
1.11
0.20
1
2-1277 ACAR
24
0303 POWERTON - 2
NEVADA
345
345
0.25
69.22
2-1277 ACAR
25
0304 POWERTON - 1
TAXEWELL (CILCO)
345
345
8.79
1
2-1277 ACAR
26
0304 POWERTON - 2
TAXEWELL (CILCO)
345
345
0.12
2-1277 ACAR
27
0403 QUAD CITIES - 1
CORDOVA
345
345
1.96
1
2-1033.5 ACSS/TW
28
0403 QUAD CITIES - 2
CORDOVA
345
345
0.17
2-1277 ACAR
29
0404 QUAD CITIES
N.W. STEEL & WIRE
345
345
33.07
1
2-1277 ACAR
30
0621 BYRON - 1
CHERRY VALLEY
345
345
0.27
13.17
1
2156 ACSR
31
0621 BYRON - 2
CHERRY VALLEY
345
345
8.07
2156 ACSR
32
0622 BYRON - 1
CHERRY VALLEY
345
345
21.51
1
2156 ACSR, 2338 A
33
0622 BYRON - 2
CHERRY VALLEY
345
345
0.03
2156 ACSR
34
0624 BYRON - 1
WEMPLETOWN
345
345
0.41
1
2156 ACSR
35
0624 BYRON - 2
WEMPLETOWN
345
345
27.87
2156 ACSR, 2-2156
36
0626 BYRON
WAYNE
345
345
59.44
1
2-1277 ACAR
37
0627 BYRON - 1
LEE COUNTY E.C.
345
345
11.11
1
2-1277 ACAR
38
0627 BYRON - 2
LEE COUNTY E.C.
345
345
0.07
2-1277 ACAR
39
0627 BYRON - 3
LEE COUNTY E.C.
345
345
0.49
2156 ACSR
40
0627 BYRON - 4
LEE COUNTY E.C.
345
345
7.80
2156 ACSR
41
0722 STATE LINE
BURNHAM
345
345
3.83
1
2338 ACAR
42
1202 DRESDEN - 1
MULBERRY
345
345
0.37
1
2156 ACSR
43
1202 DRESDEN - 2
MULBERRY
345
345
1.12
2338 ACAR
44
1220 DRESDEN - 1
ELWOOD E.C.
345
345
11.50
1
2338 ACAR
45
1220 DRESDEN - 2
ELWOOD E.C.
345
345
0.40
T2-1113 ACSR
46
1220 DRESDEN - 3
ELWOOD E.C.
345
345
0.53
2338 ACAR
47
1220 DRESDEN - 4
ELWOOD E.C.
345
345
0.16
2156 ACSR
48
1221 DRESDEN - 1
WOLFS
345
345
1.11
1
2338 ACAR
49
1221 DRESDEN - 2
WOLFS
345
345
22.72
2156 ACSR
50
1221 DRESDEN - 3
WOLFS
345
345
0.94
2156 ACSR
51
1222 DRESDEN - 1
ELWOOD E.C.
345
345
0.54
1
T2-1113,2156 ACSR
52
1222 DRESDEN - 2
ELWOOD E.C.
345
345
11.89
2338 ACAR
53
1223 DRESDEN - 1
ELECTRIC JUNCTION
345
345
0.19
28.43
1
2156 ACSR
54
1223 DRESDEN - 2
ELECTRIC JUNCTION
345
345
0.26
1.07
2338 ACAR
55
1223 DRESDEN - 3
ELECTRIC JUNCTION
345
345
0.05
1.25
2156 ACSR
56
1227 DRESDEN - 1
MULBERRY
345
345
0.56
0.18
1
2156 ACSR, 2-1033.5 ACSS/TW
57
1227 DRESDEN - 2
MULBERRY
345
345
0.11
0.69
2156 ACSR
58
1309 CRAWFORD
FISK TERMINAL
345
345
4.65
1
T2-1113 ACSR
59
1310 CRAWFORD
FISK
345
345
0.18
4.39
1
T2-1113 ACSR
60
1311 CRAWFORD - 1
GOODINGS GROVE
345
345
9.86
1
2-1277 ACAR, 2156 ACSR, 2-1033.5 ACSS/TW
61
1311 CRAWFORD - 2
GOODINGS GROVE
345
345
10.58
2156 ACSR
62
1312 CRAWFORD - 1
GOODINGS GROVE
345
345
0.33
9.62
1
2-1277 ACAR, 2156 ACSR, 2338 ACAR
63
1312 CRAWFORD - 2
GOODINGS GROVE
345
345
0.05
10.53
2156 ACSR
64
1625 WAUKEGAN
NORTHBROOK 159
345
345
0.26
21.47
1
2156 ACSR
65
1626 WAUKEGAN
NORTHBROOK 159
345
345
21.78
1
2156 ACSR
66
2001 BRAIDWOOD - 1
E. FRANKFORT
345
345
7.88
1
2-1277 ACAR
67
2001 BRAIDWOOD - 2
E. FRANKFORT
345
345
28.08
2-1277 ACAR
68
2002 BRAIDWOOD - 1
DAVIS CREEK
345
345
2.49
1
2156 ACSR
69
2002 BRAIDWOOD - 2
DAVIS CREEK
345
345
20.50
2156 ACSR
70
2003 BRAIDWOOD - 1
E. FRANKFORT
345
345
0.42
7.43
1
2-1277 ACAR
71
2003 BRAIDWOOD - 2
E. FRANKFORT
345
345
28.08
2-1277 ACAR
72
2004 BRAIDWOOD - 1
DAVIS CREEK
345
345
0.14
2.34
1
2156 ACSR
73
2004 BRAIDWOOD - 2
DAVIS CREEK
345
345
20.50
2156 ACSR
74
2101 KINCAID
LANESVILLE (AMEREN)
345
345
19.84
1
2-1277 ACAR
75
2102 KINCAID - 1
LATHAM (AMEREN)
345
345
31.14
1
2-1277 ACAR
76
2102 KINCAID - 2
LATHAM (AMEREN)
345
345
0.06
2-1277 ACAR
77
2105 KINCAID - 1
PANA
345
345
25.94
1
2338 ACAR
78
2105 KINCAID - 2
PANA
345
345
0.30
2338 ACAR
79
2105 KINCAID - 3
PANA
345
345
0.15
2338 ACAR
80
2107 MT. PULASKI - 1
LANESVILLE (AMEREN)
345
345
0.95
1
2-1277 ACAR
81
2107 MT. PULASKI - 2
LANESVILLE (AMEREN)
345
345
7.23
2-1277 ACAR
82
2218 ZION
WAUKEGAN
345
345
5.28
1
2156 ACSR
83
2219 ZION
WAUKEGAN
345
345
0.33
4.94
1
2156 ACSR
84
2221 ZION - 1
ATC
345
345
4.89
1
2156 ACSR
85
2221 ZION - 2
ATC
345
345
2.96
2156 ACSR
86
2222 ZION - 1
ATC
345
345
3.02
1
2338 ACAR
87
2222 ZION - 2
ATC
345
345
0.87
1.94
2338 ACAR
88
2222 ZION - 3
ATC
345
345
1.87
2156 ACSR
89
2222 ZION - 4
ATC
345
345
0.15
2156 ACSR
90
2223 ZION - 1
ZION E.C.
345
345
0.15
1
2156 ACSR
91
2223 ZION - 2
ZION E.C.
345
345
3.04
2338 ACAR
92
2223 ZION - 3
ZION E.C.
345
345
2.79
2338 ACAR
93
2224 ZION - 1
LIBERTYVILLE
345
345
0.25
15.20
1
2338 ACAR
94
2224 ZION - 2
LIBERTYVILLE
345
345
0.87
1.92
2338 ACAR
95
2224 ZION - 3
LIBERTYVILLE
345
345
0.26
2156 ACSR
96
2310 COLLINS - 1
KENDALL CO.
345
345
0.20
1
2156 ACSR
97
2310 COLLINS - 2
KENDALL CO.
345
345
15.18
2156 ACSR
98
2311 COLLINS - 1
DRESDEN
345
345
0.56
1
2156 ACSR
99
2311 COLLINS - 2
DRESDEN
345
345
2.05
9.48
2156 ACSR
100
2912 JOLIET
LOCKPORT
345
345
12.71
1
2156 ACSR
101
2913 JOLIET
LOCKPORT
345
345
0.07
12.65
1
2156 ACSR
102
4620 DESPLAINES 46
PROSPECT HTS, 117
345
345
0.62
4.00
1
2156 ACSR
103
4621 DESPLAINES - 1
GOLF MILL
345
345
3.38
1
2156 ACSR
104
4621 DESPLAINES - 2
GOLF MILL
345
345
0.18
2156 ACSR
105
4622 DESPLAINES - 1
GOLF MILL
345
345
3.28
1
2156 ACSR
106
4622 DESPLAINES - 2
GOLF MILL
345
345
0.05
0.15
2156 ACSR
107
6607 EAST FRANKFORT - 1
CRETE E.C.
345
345
0.09
1
2156 ACSR
108
6607 EAST FRANKFORT - 2
CRETE E.C.
345
345
0.37
1414 PE ACSR
109
6607 EAST FRANKFORT - 3
CRETE E.C.
345
345
12.22
1414 PE ACSR
110
6608 EAST FRANKFORT - 1
UNIVERSITY PARK N.  E.C.
345
345
0.08
1
2156 ACSR
111
6608 EAST FRANKFORT - 2
UNIVERSITY PARK N.  E.C.
345
345
0.13
1414 ACSR
112
6608 EAST FRANKFORT - 3
UNIVERSITY PARK N.  E.C.
345
345
0.09
5.11
1414 ACSR
113
8001 PONTIAC MIDPOINT
MCLEAN
345
345
10.33
1
2-1277 ACAR
114
8002 PONTIAC MIDPOINT - 1
BLUE MOUND
345
345
27.21
1
2-1277ACAR
115
8002 PONTIAC MIDPOINT - 2
BLUE MOUND
345
345
0.14
2-1277ACAR
116
8012 PONTIAC MIDPOINT - 1
LORETTO
345
345
0.17
1
2-1277ACAR
117
8012 PONTIAC MIDPOINT - 2
LORETTO
345
345
11.32
2-1277ACAR
118
8014 DRESDEN
PONTIAC MIDPOINT
345
345
43.28
1
2-1277 ACAR
119
8823 SKOKIE 88 - 1
GOLF MILL
345
345
0.22
1
2156 ACSR
120
8823 SKOKIE 88 - 2
GOLF MILL
345
345
4.43
2156 ACSR
121
8824 SKOKIE 88 - 1
GOLF MILL
345
345
0.06
0.16
1
2156 ACSR
122
8824 SKOKIE 88 - 2
GOLF MILL
345
345
0.02
4.48
2156 ACSR
123
9503 CHESTNUT - 1
LATHAM (AMEREN)
345
345
5.83
1
2-1277 ACAR
124
9503 CHESTNUT - 2
LATHAM (AMEREN)
345
345
0.27
2-1277 ACAR
125
9515 CHESTNUT - 1
BLUEMOUND
345
345
34.74
1
2-1277 ACAR
126
9515 CHESTNUT - 2
BLUEMOUND
345
345
0.26
2-1277 ACAR
127
10111 ITASCA
DESPLAINES 46
345
345
9.01
1
2156 ACSR
128
10112 ITASCA
DESPLAINES 46
345
345
0.41
8.67
1
2156 ACSR
129
10321 LISLE
LOMBARD
345
345
8.68
1
2156 ACSR
130
10322 LISLE - 1
LOMBARD
345
345
0.38
8.47
1
2156 ACSR
131
10322 LISLE - 2
LOMBARD
345
345
0.17
2156 ACSR
132
10801 LOCKPORT
LOMBARD
345
345
12.69
1
2156 ACSR
133
10802 LOCKPORT - 1
LOMBARD
345
345
0.10
12.37
1
2156 ACSR
134
10802 LOCKPORT - 2
LOMBARD
345
345
0.17
2156 ACSR
135
10803 LOCKPORT - 1
MCCOOK
345
345
19.05
1
2338 ACAR,2156 ACSR
136
10803 LOCKPORT - 2
MCCOOK
345
345
0.43
2156 ACSR
137
10804 LOCKPORT - 1
MCCOOK
345
345
0.21
18.92
1
2338 ACAR,2156 ACSR
138
10804 LOCKPORT - 2
MCCOOK
345
345
0.43
2156 ACSR
139
10805 LOCKPORT - 1
KENDALL CO.
345
345
16.71
1
T2-1113 ACSR
140
10806 LOCKPORT - 1
KENDALL CO.
345
345
0.15
15.95
1
T2-1113 ACSR
141
10807 LOCKPORT
LOMBARD
345
345
21.53
1
T2-1113 ACSR
142
10808 LOCKPORT
LOMBARD
345
345
0.39
20.96
1
T2-1113 ACSR
143
11119 ELECTRIC JUNCTION
AURORA E.C.
345
345
0.43
1.00
1
2338 ACAR, 2156 ACSR
144
11120 ELECTRIC JUNCTION - 1
LOMBARD
345
345
4.41
1
2156 ACSR
145
11120 ELECTRIC JUNCTION - 2
LOMBARD
345
345
0.56
4.09
2338 ACAR
146
11120 ELECTRIC JUNCTION - 3
LOMBARD
345
345
8.93
2335 ACAR
147
11124 ELECTRIC JUNCTION - 1
LOMBARD
345
345
12.20
1
2335 ACAR
148
11124 ELECTRIC JUNCTION - 2
LOMBARD
345
345
0.84
2156 ACSR
149
11124 ELECTRIC JUNCTION - 3
LOMBARD
345
345
4.59
2338 ACAR
150
11126 ELECTRIC JUNCTION - 1
WAYNE
345
345
0.34
1
2156 ACSR, 2338 ACAR
151
11126 ELECTRIC JUNCTION - 2
WAYNE
345
345
13.37
2338 ACAR, 2156 ACSR
152
11212 WILTON CENTER - 1
LORETTO
345
345
1.95
1
2-1277 ACAR
153
11212 WILTON CENTER - 2
LORETTO
345
345
38.02
2-1277 ACAR
154
11601 GOODINGS GROVE - 1
EAST FRANKFORT
345
345
10.53
1
2-1033.5ACSS/TW
155
11601 GOODINGS GROVE - 2
EAST FRANKFORT
345
345
0.28
2-1033.5ACSS/TW
156
11602 GOODINGS GROVE - 1
EAST FRANKFORT
345
345
0.03
10.50
1
2-1033.5ACSS/TW
157
11602 GOODINGS GROVE - 2
EAST FRANKFORT
345
345
0.23
2-1033.5ACSS/TW
158
11604 GOODINGS GROVE
LOCKPORT
345
345
9.02
1
2156 ACSR
159
11607 GOODINGS GROVE
BEDFORD PARK
345
345
18.51
1
2156 ACSR
160
11608 GOODINGS GROVE
BEDFORD PARK
345
345
0.15
18.43
1
2156 ACSR
161
11613 TAP
BLUE ISLAND
345
345
0.05
7.59
1
2338 ACAR
162
11613 GOODINGS GROVE - 1
WILTON CENTER
345
345
0.58
0.14
2156 ACSR, 2338 ACAR
163
11613 GOODINGS GROVE - 2
WILTON CENTER
345
345
9.63
21.09
2338 ACAR
164
11614 GOODINGS GROVE - 1
WILTON CENTER
345
345
30.60
1
2338 ACAR, 2-1277 ACAR
165
11614 GOODINGS GROVE - 2
WILTON CENTER
345
345
0.70
2338 ACAR, 2156 ACSR
166
11614 TAP
BLUE ISLAND
345
345
7.64
2338 ACAR
167
11617 GOODINGS GROVE - 1
LOCKPORT
345
345
0.08
8.80
1
2156 ACSR
168
11617 GOODINGS GROVE - 2
LOCKPORT
345
345
0.03
0.08
2156 ACSR
169
11620 GOODINGS GROVE - 1
ELWOOD
345
345
0.33
17.50
1
2156 ACSR
170
11620 GOODINGS GROVE - 2
ELWOOD
345
345
0.36
0.52
2156/T2-1113 ACSR
171
11622 GOODINGS GROVE - 1
ELWOOD
345
345
17.85
1
2156 ACSR
172
11622 GOODINGS GROVE - 2
ELWOOD
345
345
0.86
T2-1113,2156 ACSR
173
11723 PROSPECT HTS. 117
LIBERTYVILLE
345
345
15.36
1
2156 ACSR
174
11724 PROSPECT HTS. 117
DES PLAINES TSS46
345
345
4.57
1
2338 ACAR, 2156 ACSR
175
12001 LOMBARD
ITASCA
345
345
8.22
1
2156 ACSR
176
12002 LOMBARD
ITASCA
345
345
0.22
7.95
1
2156 ACSR
177
12003 LOMBARD
ELMHURST
345
345
7.98
1
2338 ACAR, 2-664.8 ACSS/TW
178
12004 LOMBARD
ELMHURST
345
345
0.15
7.77
1
2156 ACSR, 2338 ACAR, 2-664.8 ACSS/TW
179
12005 LOMBARD
DESPLAINES
345
345
0.32
16.78
1
2156 ACSR
180
12006 LOMBARD
DESPLAINES
345
345
17.09
1
2156 ACSR
181
13817 SILVER LAKE - 1
PLEASANT VALLEY
345
345
9.35
1
2156 ACSR
182
13817 SILVER LAKE - 2
PLEASANT VALLEY
345
345
0.39
2156 ACSR
183
13821 SILVER LAKE - 1
LIBERTYVILLE
345
345
0.59
16.89
1
2338 ACAR
184
13821 SILVER LAKE - 2
LIBERTYVILLE
345
345
0.19
2156 ACSR
185
14321 WOLFS - 1
ELECTRIC JUNCTION
345
345
6.29
1
2156 ACSR, 2338 ACAR
186
14321 WOLFS - 2
ELECTRIC JUNCTION
345
345
0.19
2156 ACSR
187
14401 WAYNE - 1
SILVER LAKE
345
345
0.24
19.41
1
2338 ACAR
188
14401 WAYNE - 2
SILVER LAKE
345
345
0.11
0.29
2338 ACAR
189
14402 WAYNE - 1
TOLLWAY
345
345
5.54
1
2338 ACAR, 2156 ACSR
190
14402 WAYNE - 2
TOLLWAY
345
345
0.06
2156 ACSR
191
14419 WAYNE - 1
AURORA E.C.
345
345
0.03
12.34
1
2338 ACAR
192
14419 WAYNE - 2
AURORA E.C.
345
345
0.16
2156 ACSR, 2338 ACAR
193
15324 TAYLOR
FISK
345
345
0.20
1
2156 ACSR
194
15423 LIBERTYVILLE - 1
ZION E.C.
345
345
12.33
1
2156 ACSR
195
15423 LIBERTYVILLE - 2
ZION E.C.
345
345
0.11
2156 ACSR
196
15424 LIBERTYVILLE
PROSPECT HTS, 117
345
345
0.34
14.93
1
2338 ACAR, 2156 ACSR
197
15501 NELSON - 1
LEE COUNTY E.C.
345
345
4.29
1
2338 ACAR
198
15501 NELSON - 2
LEE COUNTY E.C.
345
345
8.63
2-1277 ACAR
199
15501 NELSON - 3
LEE COUNTY E.C.
345
345
0.07
2-1277 ACAR
200
15502 NELSON - 1
ELECTRIC JUNCTION
345
345
15.92
1
2-1033.5 ACSS/TW
201
15502 NELSON - 2
ELECTRIC JUNCTION
345
345
4.65
2-1277 ACAR
202
15502 NELSON - 3
ELECTRIC JUNCTION
345
345
52.61
2-1277 ACAR
203
15503 NELSON - 1
CORDOVA
345
345
0.07
0.34
1
2-1033.5 ACSS/TW,
204
15503 NELSON - 2
CORDOVA
345
345
39.23
2-1227 ACAR
205
15503 NELSON - 3
CORDOVA
345
345
0.04
2-1277 ACAR
206
15504 NELSON
N.W. STEEL & WIRE
345
345
5.76
2.15
1
2-1277 ACAR
207
15615 CHERRY VALLEY
WEMPLETOWN
345
345
27.22
1
2156 ACSR
208
15616 CHERRY VALLEY - 1
SILVER LAKE
345
345
39.55
1
2338 ACAR, 2156 ACSR
209
15616 CHERRY VALLEY - 2
SILVER LAKE
345
345
0.98
T2-1113 ACSR
210
15925 NORTHBROOK
SKOKIE 88
345
345
5.63
1
2156 ACSR
211
15926 NORTHBROOK
SKOKIE 88
345
345
0.06
5.46
1
2156 ACSR
212
16703 PLANO - 1
ELECTRIC JUNCTION
345
345
0.12
11.48
1
2156 ACSR
213
16703 PLANO - 2
ELECTRIC JUNCTION
345
345
9.59
2156 ACSR
214
16704 PLANO - 1
ELECTRIC JUNCTION
345
345
11.60
1
2156 ACSR
215
16704 PLANO - 2
ELECTRIC JUNCTION
345
345
9.66
2156 ACSR
216
17101 WEMPLETOWN - 1
ATC INTERCONNECTION
345
345
10.40
1
2156 ACSR
217
17101 WEMPLETOWN - 2
ATC INTERCONNECTION
345
345
0.99
2156 ACSR
218
17102 WEMPLETOWN - 1
ATC INTERCONNECTION
345
345
0.06
10.34
1
2156 ACSR
219
17102 WEMPLETOWN - 2
ATC INTERCONNECTION
345
345
0.99
2156 ACSR
220
17701 BURNHAM - 1
BLUE ISLAND
345
345
7.79
1
2338 ACAR
221
17701 BURNHAM - 2
BLUE ISLAND
345
345
0.60
2156 ACSR
222
17702 BURNHAM
BLUE ISLAND
345
345
0.10
8.13
1
2338 ACAR
223
17703 BURNHAM
NIPSCO
345
345
8.51
1
2338 ACAR
224
17704 BURNHAM - 1
DAVIS CREEK
345
345
17.49
1
2156 ACSR, T2-1113 ACSR, 2338 ACAR
225
17704 BURNHAM - 2
DAVIS CREEK
345
345
32.36
2156 ACSR, T2-1113 ACSR
226
17705 BURNHAM
SHEFFIELD (NIPSCO)
345
345
0.04
3.68
1
2338 ACAR
227
17723 BURNHAM - 1
STATE LINE
345
345
0.05
1
2156 ACSR
228
17723 BURNHAM - 2
STATE LINE
345
345
3.80
2156 ACSR
229
17723 STATE LINE - 1
TAYLOR
345
345
8.84
2156 ACSR, 2-1277 ACAR
230
17723 STATE LINE - 2
TAYLOR
345
345
0.13
2156 ACSR
231
17724 BURNHAM
STATE LINE
345
345
0.20
3.71
1
2156 ACSR
232
17724 STATE LINE - 1
TAYLOR
345
345
0.50
8.47
2156 ACSR, 2-1277 ACAR
233
17724 STATE LINE - 2
TAYLOR
345
345
0.13
2156 ACSR
234
17907 DAVIS CREEK - 1
BLOOM
345
345
0.14
8.22
1
2156 ACSR
235
17907 DAVIS CREEK - 2
BLOOM
345
345
24.00
T2-1113 ACSR
236
17907 DAVIS CREEK - 3
BLOOM
345
345
0.17
4.73
2156 ACSR
237
17907 DAVIS CREEK - 4
BLOOM
345
345
0.06
0.17
T2-1113 ACSR
238
17908 BURNHAM
BLOOM
345
345
0.25
12.17
1
2156 ACSR, 2338 ACAR
239
18502 TOLLWAY - 1
LIBERTYVILLE
345
345
22.84
1
2338 ACAR
240
18502 TOLLWAY - 2
LIBERTYVILLE
345
345
7.69
2156 ACSR
241
18502 TOLLWAY - 3
LIBERTYVILLE
345
345
0.12
2338 ACAR
242
18502 TOLLWAY - 4
LIBERTYVILLE
345
345
0.12
2156 ACSR
243
18806 MT. PULASKI - 1
DEER CREEK
345
345
0.73
1
2-1277 ACAR
244
18806 MT. PULASKI - 2
DEER CREEK
345
345
15.82
2-1277 ACAR
245
18806 MT. PULASKI - 3
DEER CREEK
345
345
1.09
2-1277 ACAR
246
19601 KATYDID - 1
GOODINGS GROVE
345
345
0.06
1
2-1277 ACAR, 2156
247
19601 KATYDID - 2
GOODINGS GROVE
345
345
53.45
2-1277 ACAR, 2156
248
93505 KENDALL CO. - 1
DRESDEN
345
345
0.38
1
2338 ACAR, 2156 A
249
93505 KENDALL CO. - 2
DRESDEN
345
345
7.38
2338 ACAR, 2-1277
250
97008 UNIVERSITY PK.  E.C. - 1
I & M POWER
345
345
4.57
7.03
1
1414 ACSR
251
97008 UNIVERSITY PK.  E.C. - 2
I & M POWER
345
345
0.62
1414 ACSR, 2156 A
252
94507 CRETE E.C. - 1
N.I.P.S.CO.
345
345
4.54
1
1414 ACSR, 2156 A
253
94507 CRETE E.C. - 2
N.I.P.S.CO.
345
345
0.42
1414 ACSR, 2156 A
254
345KV LINES
345kV LINES
255
1309 FISK TERMINAL
WEST LOOP
345
345
4.87
1600mm2 XLPE
256
15323 TAYLOR
WEST LOOP
345
345
3.30
1
1600mm2 XLPE
257
15324 TAYLOR
FISK
345
345
2.20
1600mm2 XLPE
258
17723X TAYLOR
GARFIELD
345
345
6.08
2500KCMIL
259
17724Y TAYLOR - 1
GARFIELD
345
345
6.08
2500KCMIL
260
17724X TAYLOR
GARFIELD
345
345
6.11
1600mm2 XLPE
261
17724Y TAYLOR - 2
GARFIELD
345
345
6.10
1600mm2 XLPE
262
138KV LINES OVERHEAD
263
2 STEAM PLANT ROAD - 1
TWOMBLY ROAD
138
138
2.63
1
556.5 ACSR
264
2 STEAM PLANT ROAD - 2
TWOMBLY ROAD
138
138
0.47
556.5 ACSR
265
4 STEAM PLANT ROAD
CARON ROAD
138
138
0.06
1
556.5 ACSR
266
0108 LASALLE CO. - 1
SW TIE L-1205
138
138
0.37
1
1113 ACSR, 664.8 ACSS/TW
267
0108 LASALLE CO. - 2
SW TIE L-1205
138
138
2.95
664.8 ACSS, 477&1
268
0108 LASALLE CO. - 3
SW TIE L-1205
138
138
0.30
664.8 ACSS/TW
269
0108 LASALLE CO. - 4
SW TIE L-1205
138
138
12.89
300CU,477ACS
270
0108 TAP
SW TIE L-6102
138
138
0.06
477 ACSR
271
0112 LASALLE CO.
KICKAPOO CREEK
138
138
1.35
1113 ACSR, T2-555
272
0321 POWERTON - 1
TOULON
138
138
42.21
1
477,1113 ACSR
273
0321 POWERTON - 2
TOULON
138
138
0.65
1113 ACSR, 922
274
0703 STATE LINE
HEGEWISCH
138
138
0.26
2.39
1
1113 ACSR
275
0703 TAP - 1
LTV STEEL
138
138
0.07
477ACSR
276
0703 TAP - 2
RIVER E.C.
138
138
0.39
477,636, 2-336.4A
277
0703 TAP - 3
RIVER E.C.
138
138
1.87
477,636,
278
0704 STATE LINE - 1
RIVER E.C.
138
138
1.15
1
336.4,477,636,111
279
0704 STATE LINE - 2
RIVER E.C.
138
138
0.21
1.79
636, 1113ACSR
280
0704 STATE LINE - 3
RIVER E.C.
138
138
0.16
1113 ACSR
281
0704 TAP - 1
TOWER AUTOMOTIVE
138
138
0.10
0.16
1113 ACSR
282
0704 TAP - 2
TOWER AUTOMOTIVE
138
138
0.11
1113 ACSR
283
0706 STATE LINE - 1
CALUMET
138
138
1.28
1
1113,2156 ACSR
284
0706 STATE LINE - 2
CALUMET
138
138
0.10
1113,2156 ACSR
285
0706 STATE LINE - 3
CALUMET
138
138
0.07
1113 ACSR
286
0707 STATE LINE - 1
CALUMET
138
138
0.59
1
750 CU / 1113,215
287
0707 STATE LINE - 2
CALUMET
138
138
1.10
2156 ACSR
288
0707 TAP
TAP TO T-3030
138
138
0.18
2156 ACSR
289
0708 STATE LINE - 1
CALUMET
138
138
0.24
0.61
1
750 CU / 1113,215
290
0708 STATE LINE - 2
CALUMET
138
138
0.12
0.99
2156 ACSR
291
0708 TAP - 1
HARBOR
138
138
0.08
2156 ACSR
292
0708 TAP - 2
HARBOR
138
138
0.21
2156 ACSR
293
0716 ILL-IND STATE LINE - 1
CALUMET
138
138
0.09
1
1113 ACSR
294
0716 ILL-IND STATE LINE - 2
CALUMET
138
138
0.24
1.07
2-1277.2 ACAR / 1
295
0716 ILL-IND STATE LINE - 3
CALUMET
138
138
0.13
2156 ACSR
296
0901 JOLIET - 1
EAST FRANKFORT
138
138
14.75
1
300CU/636,1113/66
297
0901 JOLIET - 2
EAST FRANKFORT
138
138
0.08
0.30
300 CU
298
0901 TAP - 1
DAVIS CREEK
138
138
19.52
2-556.5,1113 ACSR
299
0901 TAP - 2
DAVIS CREEK
138
138
0.17
2-556.5 ACSR
300
0901 TAP - 3
DAVIS CREEK
138
138
0.76
1113 ACSR
301
0901 TAP - 4
DAVIS CREEK
138
138
0.06
0.47
1113 ACSR
302
0902 JOLIET - 1
EAST FRANKFORT
138
138
3.83
11.24
1
477,1113 ACSR, 66
303
0902 JOLIET - 2
EAST FRANKFORT
138
138
0.09
477 ACSR
304
0902 TAP - 1
DAVIS CREEK
138
138
10.69
636 ACSR
305
0902 TAP - 2
DAVIS CREEK
138
138
8.70
636 ACSR
306
0902 TAP - 3
DAVIS CREEK
138
138
0.19
2.41
636,1113 ACSR
307
0902 TAP - 4
DAVIS CREEK
138
138
0.06
0.63
1113 ACSR
308
0903 JOLIET - 1
DRESDEN
138
138
0.24
7.67
1
1113 ACSR
309
0903 JOLIET - 2
DRESDEN
138
138
0.49
6.94
1113 ACSR
310
0904 JOLIET - 1
DRESDEN
138
138
0.33
9.22
1
300 CU / 1113 ACS
311
0904 JOLIET - 2
DRESDEN
138
138
0.58
1113 ACSR
312
0904 JOLIET - 3
DRESDEN
138
138
4.87
0.08
1113 ACSR
313
0905 JOLIET - 1
WILL COUNTY
138
138
5.20
7.08
1
477, T2-556.5 ACSR, 763.0 ACCR/TW
314
0905 JOLIET - 2
WILL COUNTY
138
138
2.65
T2-556.5 ACSR, 664.8 ACSS/TW
315
0905 TAP
JOLIET TR.# 79
138
138
0.01
477 ACSR
316
0906 JOLIET - 1
WILL COUNTY
138
138
7.86
7.88
1
477, 900, 1113, T2-556.5 ACSR, 664.8 ACSS/TW
317
0906 JOLIET - 2
WILL COUNTY
138
138
0.82
T2-556.5 ACSR, 664.8 ACSS/TW
318
0907 JOLIET - 1
WOLFS
138
138
2.85
15.60
1
300 CU / 1113 ACW
319
0907 JOLIET - 2
WOLFS
138
138
0.08
1113 ACSR
320
0907 JOLIET - 3
WOLFS
138
138
0.06
300 CU
321
0908 JOLIET - 1
SHOREWOOD
138
138
0.34
7.79
1
1113 ACSR
322
0908 JOLIET - 2
SHOREWOOD
138
138
0.08
1113 ACSR
323
0908 JOLIET - 3
SHOREWOOD
138
138
0.13
5.64
1113 ACSR
324
1106 FISK
QUARRY
138
138
0.21
1
1113 ACSR
325
1108 FISK
QUARRY
138
138
0.17
1
1113ACSR
326
1205 DRESDEN - 1
SW TIE L-0108
138
138
8.30
8.20
1
300 CU / 477,1113
327
1205 DRESDEN - 2
SW TIE L-0108
138
138
0.07
477,1113 ACSR
328
1205 TAP
MAZON
138
138
0.09
477 ACSR
329
1206 DRESDEN - 1
CHANNAHON WEST
138
138
2.55
3.75
477,1113 ACSR
330
1206 DRESDEN - 2
CHANNAHON WEST
138
138
0.28
1113 ACSR
331
1206 TAP
EQUISTAR
138
138
0.11
0.09
332
1207 DRESDEN - 1
WILMINGTON
138
138
13.05
1
636 ACSR
333
1207 DRESDEN - 2
WILMINGTON
138
138
0.14
636 ACSR
334
1210 DRESDEN - 1
CARGO COURT
138
138
2.00
1
1113 AA / 1113 AC
335
1210 DRESDEN -2
CARGO COURT
138
138
2.94
1113 AA / 1113 AC
336
1306 RIDGELAND - 1
CRAWFORD
138
138
0.05
0.73
1
1113 ACSR
337
1306 RIDGELAND - 2
CRAWFORD
138
138
0.36
2.50
1113 ACSR
338
1315 RIDGELAND - 1
CRAWFORD
138
138
0.16
1.20
1
900, 1113 ACSR
339
1315 RIDGELAND - 2
CRAWFORD
138
138
0.27
2.66
1113 ACSR
340
1315 RIDGELAND - 3
CRAWFORD
138
138
0.03
900 ACSR
341
1321 CRAWFORD - 1
CONGRESS
138
138
0.31
0.40
1
1113 ACSR
342
1321 CRAWFORD - 2
CONGRESS
138
138
0.28
4.02
1113 ACSR
343
1322 CRAWFORD - 1
BEDFORD PARK
138
138
0.29
3.13
1
1113 ACSR
344
1322 CRAWFORD - 2
BEDFORD PARK
138
138
0.02
4.31
2-556.5,1113 ACSR
345
1322 CRAWFORD - 3
BEDFORD PARK
138
138
0.05
1113 ACSR
346
1323 CRAWFORD - 1
CONGRESS
138
138
0.67
1
1113 ACSR
347
1323 CRAWFORD - 2
CONGRESS
138
138
4.44
1113 ACSR
348
1324 CRAWFORD - 1
BEDFORD PARK
138
138
0.28
2.82
1
1113 ACSR
349
1324 CRAWFORD - 2
BEDFORD PARK
138
138
0.02
4.26
2-556.5,1113 ACSR
350
1324 CRAWFORD - 3
BEDFORD PARK
138
138
0.41
1113 ACSR
351
1404 POWERTON
JUNCTION WITH AMEREN
138
138
0.37
477 ACSR
352
1603 WAUKEGAN - 1
SW TIE L-4203
138
138
0.28
14.55
1
300 CU / 477,1113
353
1603 WAUKEGAN - 2
SW TIE L-4203
138
138
0.32
0.34
300 CU / 477,1113
354
1604 WAUKEGAN - 1
LIBERTYVILLE
138
138
0.24
13.45
1
1113 ACSR
355
1604 WAUKEGAN - 2
LIBERTYVILLE
138
138
0.10
0.50
1113 ACSR
356
1604 WAUKEGAN - 3
LIBERTYVILLE
138
138
0.05
1113 ACSR
357
1605 WAUKEGAN - 1
HIGHLAND PARK
138
138
15.80
0.00
1
1113 ACSR
358
1605 WAUKEGAN - 2
HIGHLAND PARK
138
138
0.35
1113 ACSR
359
1605 WAUKEGAN - 3
HIGHLAND PARK
138
138
0.98
0.00
1113,2156 ACSR
360
1606 WAUKEGAN - 1
HIGHLAND PARK
138
138
0.10
15.80
1
1113 ACSR
361
1606 WAUKEGAN - 2
HIGHLAND PARK
138
138
0.30
1113 ACSR
362
1606 WAUKEGAN - 3
HIGHLAND PARK
138
138
0.53
0.48
1113,2156 ACSR
363
1607 WAUKEGAN - 1
SW TIE L-4202
138
138
0.32
14.76
1
300CU/1113ACSR/
364
1607 WAUKEGAN - 2
SW TIE L-4202
138
138
0.19
0.34
300CU/1113ACSR/
365
1607 TAP
ROUND LAKE
138
138
0.03
477 ACSR
366
1608 WAUKEGAN - 1
LIBERTYVILLE
138
138
0.23
13.47
1
1113 ACSR
367
1608 WAUKEGAN - 2
LIBERTYVILLE
138
138
0.09
0.50
1113 ACSR
368
1608 WAUKEGAN - 3
LIBERTYVILLE
138
138
0.05
1113 ACSR
369
1609 WAUKEGAN - 1
ZION TDC 282
138
138
5.54
1
1113 ACSR
370
1609 WAUKEGAN - 2
ZION TDC 282
138
138
0.15
900,1113 ACSR
371
1609 WAUKEGAN - 3
ZION TDC 282
138
138
4.41
1.79
1113 ACSR
372
1609 WAUKEGAN - 4
ZION TDC 282
138
138
0.31
1113 ACSR
373
1802 WILL COUNTY - 1
ARGONNE
138
138
0.45
7.08
1
1113 ACSR
374
1802 WILL COUNTY - 2
ARGONNE
138
138
0.28
0.43
1113 ACSR
375
1802 WILL COUNTY - 3
ARGONNE
138
138
0.07
1113 ACSR
376
1803 WILL COUNTY - 1
BOLINGBROOK BREAKER
138
138
2.50
1
2-556.5 ACSR
377
1803 WILL COUNTY - 2
BOLINGBROOK BREAKER
138
138
4.00
2-556.5,1113 ACSR
378
1804 WILL COUNTY - 1
WOLFS
138
138
5.44
9.07
1
477,900,1113
379
1804 WILL COUNTY - 2
WOLFS
138
138
0.08
1113 ACSR
380
1807 WILL COUNTY - 1
ARGONNE NAT'L LAB
138
138
0.50
7.07
1
1113 ACSR
381
1807 WILL COUNTY - 2
ARGONNE NAT'L LAB
138
138
0.04
1113 ACSR
382
1807 WILL COUNTY - 3
ARGONNE NAT'L LAB
138
138
0.43
1113 ACSR
383
1808 WILL COUNTY - 1
GOODINGS GROVE
138
138
0.57
8.92
1
900 ACSR
384
1808 WILL COUNTY - 2
GOODINGS GROVE
138
138
0.13
0.55
900 ACSR
385
1809 WILL COUNTY - 1
NORMANTOWN
138
138
0.47
0.94
1
1033.5ACSS/TW, 2-
386
1809 WILL COUNTY - 2
NORMANTOWN
138
138
0.03
2.22
2-566.5, 2156ACSR
387
1811 WILL COUNTY - 1
GOODINGS GROVE
138
138
0.91
8.49
1
900 ACSR
388
1811 WILL COUNTY - 2
GOODINGS GROVE
138
138
0.60
900 ACSR
389
4202 SILVER LAKE - 1
SW TIE L-1607
138
138
0.37
13.68
1
300 CU / 477,1113
390
4202 SILVER LAKE - 2
SW TIE L-1607
138
138
0.14
0.13
1113 ACSR
391
4203 SILVER LAKE - 1
SW TIE L-1603
138
138
10.00
4.00
1
477,1113 ACSR
392
4203 SILVER LAKE - 2
SW TIE L-1603
138
138
0.18
0.13
477 ACSR
393
4203 SILVER LAKE - 3
SW TIE L-1603
138
138
0.07
1113 ACSR
394
4203 TAP
ROUND LAKE
138
138
0.05
1113 ACSR
395
4605 DESPLAINES 46 - 1
ELK GROVE
138
138
0.17
4.14
1
1113 ACSR
396
4605 DESPLAINES 46 - 2
ELK GROVE
138
138
0.20
1113,2156 ACSR
397
4609 DESPLAINES 46 - 1
DESPLAINES 198
138
138
0.12
3.06
1
1113 ACSR, 664.8
398
4609 DESPLAINES 46 - 2
DESPLAINES 198
138
138
0.23
1113 ACSR
399
4606 DESPLAINES 46 - 1
ELK GROVE
138
138
4.08
1
1113 ACSR
400
4606 DESPLAINES 46 - 2
ELK GROVE
138
138
0.38
1113 ACSR
401
4608 DESPLAINES 46 - 1
DESPLAINES 198
138
138
0.32
3.03
1
1113 ACSR, 664.8
402
4608 DESPLAINES 46 - 2
DESPLAINES 198
138
138
0.07
1113 ACSR
403
4608 DESPLAINES 46 - 3
DESPLAINES 198
138
138
0.10
1113 ACSR
404
4610 DESPLAINES 46 - 1
GOLF MILL
138
138
0.06
3.46
1
1113 ACSR
405
4610 DESPLAINES 46 - 2
GOLF MILL
138
138
0.05
1113 ACSR
406
4610 DESPLAINES 46 - 3
GOLF MILL
138
138
0.16
1113 ACSR
407
4611 DESPLAINES 46 - 1
GOLF MILL
138
138
3.47
1
1113 ACSR
408
4611 DESPLAINES 46 - 2
GOLF MILL
138
138
0.04
1113 ACSR
409
4611 DESPLAINES 46 - 3
GOLF MILL
138
138
0.30
1113 ACSR
410
5103 MCCOOK - 1
WILLOW SPRINGS
138
138
0.42
4.86
1
1113 ACSR
411
5103 MCCOOK - 2
WILLOW SPRINGS
138
138
0.09
1113 ACSR
412
5103 MCCOOK - 3
WILLOW SPRINGS
138
138
0.09
1113 ACSR
413
5103 TAP - 1
BEDFORD PARK
138
138
0.96
1113 ACSR
414
5103 TAP - 2
BEDFORD PARK
138
138
4.20
477,1113 ACSR
415
5104 MCCOOK - 1
BEDFORD PARK
138
138
2.50
1
900,1113 ACSR, 10
416
5104 MCCOOK - 2
BEDFORD PARK
138
138
1.06
0.96
1113 ACSR, 1033.5
417
5104 MCCOOK - 3
BEDFORD PARK
138
138
1.94
900 ACSR
418
5104 MCCOOK - 4
BEDFORD PARK
138
138
1.10
900 ACSR
419
5104 TAP - 1
ARGONNE LABS
138
138
8.33
900 ACSR
420
5104 TAP - 2
ARGONNE LABS
138
138
0.10
1113 ACSR
421
5105 RIDGELAND
MCCOOK
138
138
0.33
1.78
1
900,1113 ACSR
422
5107 MCCOOK - 1
RIDGELAND
138
138
0.40
1.80
1
1033.5ACSS/TW, 2-
423
5107 MCCOOK - 2
RIDGELAND
138
138
0.20
1033.5 ACSS/TW
424
5117 MCCOOK - 1
BELLWOOD
138
138
6.78
1
1113 AA / 1113 AC
425
5117 MCCOOK - 2
BELLWOOD
138
138
1.38
1113 AA / 1113 AC
426
5118 MCCOOK - 1
BELLWOOD
138
138
0.02
6.33
1
1113 AA / 1113 AC
427
5118 MCCOOK - 2
BELLWOOD
138
138
0.12
1.60
1113 AA / 1113 AC
428
6101 STREATOR - 1
PUTNAM (AMEREN)
138
138
30.10
0.00
1
300 CU / 300,477 ACSR
429
6101 STREATOR - 2
PUTNAM (AMEREN)
138
138
0.46
477, 2-556.5 ACSR
430
6102 STREATOR - 1
KICKAPOO CREEK
138
138
0.11
9.34
1
477 ACSR, 664.8 ACSS/TW
431
6102 STREATOR - 2
KICKAPOO CREEK
138
138
2.07
636 ACSR, 477
432
6102 STREATOR - 3
KICKAPOO CREEK
138
138
11.37
477 ACSR
433
6102 STREATOR - 4
KICKAPOO CREEK
138
138
0.01
1113 KCMIL
434
6102 TAP
MARSEILLES S.S.
138
138
0.01
477 ACSR
435
6603 EAST FRANKFORT - 1
MATTESON
138
138
0.10
5.36
1
300 CU / 477,1113
436
6603 EAST FRANKFORT - 2
MATTESON
138
138
0.54
1113 ACSR,664.8 A
437
6603 EAST FRANKFORT - 3
MATTESON
138
138
0.07
1113 ACSR
438
6604 EAST FRANKFORT - 1
MATTESON
138
138
0.03
5.82
1
477, 664.8 ACSS/T
439
6604 EAST FRANKFORT - 2
MATTESON
138
138
0.13
1113 ACSR
440
6604 EAST FRANKFORT - 3
MATTESON
138
138
0.11
1113 ACSR
441
6605 EAST FRANKFORT - 1
UNIVERSITY PARK
138
138
0.05
1
1113 ACSR
442
6605 EAST FRANKFORT - 2
UNIVERSITY PARK
138
138
5.34
1113 ACSR
443
6606 EAST FRANKFORT - 1
UNIVERSITY PARK
138
138
5.34
1
1113 ACSR
444
6606 EAST FRANKFORT - 2
UNIVERSITY PARK
138
138
0.04
1113 ACSR
445
6721 CONGRESS - 1
ROCKWELL
138
138
0.01
0.25
1
1113 ACSR
446
6721 CONGRESS - 2
ROCKWELL
138
138
0.01
0.94
1113 ACSR
447
6721 CONGRESS - 3
ROCKWELL
138
138
0.08
1113 ACSR
448
6723 CONGRESS - 1
ROCKWELL
138
138
0.03
0.36
1
1113 ACSR
449
6723 CONGRESS - 2
ROCKWELL
138
138
0.91
1113 ACSR
450
7305 CHICAGO HTS. - 1
BLOOM
138
138
0.11
1
1113 ACSR
451
7305 CHICAGO HTS. - 2
BLOOM
138
138
0.32
1113 ACSR
452
7305 CHICAGO HTS. - 3
BLOOM
138
138
0.75
1.29
1113 ACSR
453
7306 CHICAGO HTS. - 1
BLOOM
138
138
0.05
1
1113 ACSR
454
7306 CHICAGO HTS. - 2
BLOOM
138
138
2.19
1113 ACSR
455
7306 CHICAGO HTS. - 3
BLOOM
138
138
0.24
1113 ACSR
456
7307 CHICAGO HTS. - 1
BURNHAM
138
138
1.41
4.39
1
1113,2338 ACSR
457
7307 CHICAGO HTS. - 2
BURNHAM
138
138
0.15
0.18
1113 ACSR
458
7307 CHICAGO HTS. - 3
BURNHAM
138
138
3.74
1113 ACSR
459
7411 KEWANEE
AMEREN KEEMIN
138
138
6.91
1
477 ACSR
460
7413 KEWANEE - 1
CRESCENT RIDGE
138
138
0.18
15.23
1
300 CU / 477 ACSR
461
7413 KEWANEE - 2
CRESCENT RIDGE
138
138
0.02
1113 ACSR
462
7421 KEWANEE - 1
TOULON
138
138
11.70
1
477 ACSR
463
7421 KEWANEE - 2
TOULON
138
138
0.04
1113 ACSR
464
7423 KEWANEE - 1
EDWARD STA (CILCO)
138
138
0.18
50.04
1
477 ACSR
465
7423 KEWANEE - 2
EDWARD STA (CILCO)
138
138
0.47
0.01
1113 ACSR
466
7611 BLUE ISLAND - 1
WILDWOOD
138
138
0.13
3.81
1
900 ACSR
467
7611 BLUE ISLAND - 2
WILDWOOD
138
138
0.13
900 ACSR
468
7612 BLUE ISLAND - 1
WILDWOOD
138
138
0.20
3.74
1
900,1113 ACSR
469
7612 BLUE ISLAND - 2
WILDWOOD
138
138
0.01
0.13
900 ACSR
470
7615 BLUE ISLAND - 1
SW TIE L-11603
138
138
3.44
0.36
1
1113 ACSR
471
7616 BLUE ISLAND - 2
SW TIE L-11609
138
138
0.34
3.43
1
1113 ACSR
472
7713 MAZON - 1
CORBIN (AMEREN)
138
138
34.42
0.00
1
300 CU, 477 ACSR
473
7713 MAZON - 2
CORBIN (AMEREN)
138
138
0.15
0.00
1113 ACSR
474
7719 MAZON - 1
CHANNAHON WEST
138
138
5.73
4.29
1
3000 CU/1113
475
7719 MAZON - 2
CHANNAHON WEST
138
138
0.07
1113 ACSR
476
7719 MAZON - 3
CHANNAHON WEST
138
138
0.07
266.5 ACSR
477
7719 TAP
SW TIE L-7413
138
138
0.07
300 CU
478
7902 SPAULDING - 1
TOLLWAY
138
138
0.22
3.79
1
1113,2156 ACSR
479
7902 SPAULDING - 2
TOLLWAY
138
138
0.03
0.15
2156 ACSR
480
7903 SPAULDING - 1
TOLLWAY
138
138
0.13
3.79
1
1113,2156 ACSR
481
7903 SPAULDING - 2
TOLLWAY
138
138
0.10
0.15
1113 ACSR
482
7903 SPAULDING - 3
TOLLWAY
138
138
0.09
1113 ACSR
483
7910 SPAULDING - 1
WAYNE
138
138
0.08
1.23
1
1113 ACSR
484
7910 SPAULDING - 2
WAYNE
138
138
0.16
1113,2156 ACSR
485
7910 SPAULDING - 3
WAYNE
138
138
0.25
1113 ACSR
486
7915 SPAULDING - 1
WAYNE
138
138
0.44
1
1113,2156 ACSR
487
7915 SPAULDING - 2
WAYNE
138
138
0.02
1.19
1113 ACSR
488
8221 CROSBY - 1
ROCKWELL
138
138
0.08
1.53
1
1113 ACSR
489
8221 CROSBY - 2
ROCKWELL
138
138
0.01
0.29
1113 ACSR
490
8223 CROSBY - 1
ROCKWELL
138
138
0.08
1.51
1
1113 ACSR
491
8223 CROSBY - 2
ROCKWELL
138
138
0.02
0.29
1113 ACSR
492
8607 DAVIS CREEK - 1
WILMINGTON
138
138
0.14
1.83
1
1113 ACSR
493
8607 DAVIS CREEK - 2
WILMINGTON
138
138
0.68
1113 ACSR
494
8607 DAVIS CREEK - 3
WILMINGTON
138
138
21.58
0.24
636 ACSR, 113 ACSR
495
8801 SKOKIE 88 - 1
GOLF MILL
138
138
4.41
1
1113 ACSR
496
8801 SKOKIE 88 - 2
GOLF MILL
138
138
0.03
1113 ACSR
497
8801 SKOKIE 88 - 3
GOLF MILL
138
138
0.20
1113 ACSR
498
8802 SKOKIE 88 - 1
GOLF MILL
138
138
0.07
4.27
1
1113 ACSR
499
8802 SKOKIE 88 - 2
GOLF MILL
138
138
0.04
1113 ACSR
500
8802 SKOKIE 88 - 3
GOLF MILL
138
138
0.15
1113 ACSR
501
8803 SKOKIE 88 - 1
DEVON
138
138
0.09
1.78
1
900,1113 ACSR
502
8803 SKOKIE 88 - 2
DEVON
138
138
0.15
1.45
1113 ACSR
503
8803 SKOKIE 88 - 3
DEVON
138
138
0.17
900,1113 ACSR
504
8805 SKOKIE 88 - 1
NORTHBROOK 159
138
138
3.95
0.00
1
1113 ACSR
505
8805 SKOKIE 88 - 2
NORTHBROOK 159
138
138
0.85
0.73
1113 ACSR
506
8806 SKOKIE 88 - 1
NORTHBROOK 159
138
138
0.28
4.33
1
1113 ACSR
507
8806 SKOKIE 88 - 2
NORTHBROOK 159
138
138
0.71
0.23
1113 ACSR
508
8809 SKOKIE 88 - 1
DEVON
138
138
0.09
1.86
1
1113 ACSR
509
8809 SKOKIE 88 - 2
DEVON
138
138
0.27
1.42
1113 ACSR
510
8810 SKOKIE 88 - 1
DEVON
138
138
3.49
1
1113 ACSR
511
8810 SKOKIE 88 - 2
DEVON
138
138
0.19
1113 ACSR
512
8603 DAVIS CREEK - 1
BRADLEY
138
138
0.33
1
1113 ACSR
513
8603 DAVIS CREEK - 2
BRADLEY
138
138
6.00
2-556.5,1113 ACSR
514
8603 TAP - 1
CSL BEHRING
138
138
0.59
1113 ACSR
515
8605 DAVIS CREEK - 1
BRADLEY
138
138
2.15
2.51
1
2-556.5,1113 ACSR
516
8605 DAVIS CREEK - 2
BRADLEY
138
138
2.94
1113 ACSR
517
8605 TAP - 1
CSL BEHRING
138
138
0.12
0.51
2-556.5,1113 ACSR
518
9117 CARGO COURT - 1
SHOREWOOD
138
138
3.21
1
1113 AA
519
9117 CARGO COURT - 2
SHOREWOOD
138
138
0.49
4.24
1113 ACSR
520
10117 ITASCA - 1
TONNE
138
138
0.12
0.43
1
2156 ACSR
521
10117 ITASCA - 2
TONNE
138
138
1.32
1033.5 ACSS/TW
522
10118 ITASCA - 1
TONNE
138
138
0.13
0.44
1
2156 ACSR
523
10118 ITASCA - 2
TONNE
138
138
1.29
1033.5 ACSS/TW
524
10301 LISLE - 1
LOMBARD
138
138
0.53
7.93
1
1113,2156,2-1113A
525
10301 LISLE - 2
LOMBARD
138
138
0.32
900 ACSR
526
10301 LISLE - 3
LOMBARD
138
138
0.06
1113, 2156 ACSR
527
10302 LISLE - 1
LOMBARD
138
138
0.18
1
900 ACSR
528
10302 LISLE - 2
LOMBARD
138
138
0.57
8.06
1113,2156,2-1113A
529
10314 LISLE
BOLINGBROOK
138
138
0.16
7.41
1
1113, 2-556.6ACSR
530
10319 LISLE - 1
BOLINGBROOK
138
138
0.03
1
1113ACSR
531
10319 LISLE - 2
BOLINGBROOK
138
138
7.54
1113, 2-556.6ACSR
532
10714 DIXON - 1
MCGIRR ROAD
138
138
1.57
1
763.0ACSR/TW,
533
10714 DIXON - 2
MCGIRR ROAD
138
138
23.42
763.0ACSR/TW, 2-5
534
10721 DIXON - 1
STILLMAN VALLEY
136
138
10.49
3.94
1
1113 ACSR, 2156
535
10721 DIXON - 2
STILLMAN VALLEY
138
138
1.53
1113 ACSR, 2-556R
536
10721 DIXON - 3
STILLMAN VALLEY
138
138
0.16
1113 ACSR
537
10721 DIXON - 4
STILLMAN VALLEY
138
138
17.64
1113 ACSR, 2-1277
538
11102 ELECTRIC JUNCTION - 1
WOLFS
138
138
0.54
5.51
1
1113 ACSR, 1033.5
539
11102 ELECTRIC JUNCTION - 2
WOLFS
138
138
0.24
1113 ACSR
540
11103 ELECTRIC JUNCTION - 1
AURORA E.C.
138
138
0.11
1
1113 ACSR
541
11103 ELECTRIC JUNCTION - 2
AURORA E.C.
138
138
1.15
1113 ACSR
542
11105 ELECTRIC JUNCTION - 1
AURORA E.C.
138
138
0.32
0.74
1
1113 ACSR
543
11105 ELECTRIC JUNCTION - 2
AURORA E.C.
138
138
0.05
0.07
1113 ACSR
544
11106 ELECTRIC JUNCTION - 1
WATERMAN
138
138
0.30
9.35
1
1113 ACSR
545
11106 ELECTRIC JUNCTION - 2
WATERMAN
138
138
19.31
0.48
2-556.5 ACSR
546
11106 TAP
CREGO ROAD
138
138
3.97
2-556.5 ACSR,1113
547
11107 ELECTRIC JUNCTION - 1
NAPERVILLE
138
138
0.20
1.27
1
1113 ACSR
548
11107 ELECTRIC JUNCTION - 2
NAPERVILLE
138
138
1.40
1113 ACSR
549
11107 ELECTRIC JUNCTION - 3
NAPERVILLE
138
138
0.07
2-556.5,1113 ACSR
550
11110 ELECTRIC JUNCTION - 1
WOLFS
138
138
2.74
3.22
1
2-556.5,1113 ACSR
551
11110 ELECTRIC JUNCTION - 2
WOLFS
138
138
0.25
2156 ACSR
552
11110 TAP - 1
NAPERVILLE
138
138
0.06
1.27
1113 ACSR
553
11110 TAP - 2
NAPERVILLE
138
138
0.05
1113 ACSR
554
11301WATERMAN - 1
SANDWICH
138
138
0.77
0.48
1
1113 ACSR
555
11301WATERMAN - 2
SANDWICH
138
138
14.28
2-556.5,1113 ACSR
556
11301 TAP
ROW BREAKER AT
138
138
0.01
1113 ACSR
557
11323 WATERMAN
HAUMESSER ROAD
138
138
5.46
1
664.8 ACSS/TW, 11
558
11323 TAP
CREGO ROAD
138
138
5.41
2-556.4, 2156ACSR
559
11413 NORTHWEST
CLYBOURN-CROSBY
138
138
0.02
0.09
1
1113 ACSR
560
11416 NORTHWEST - 1
SKOKIE 88
138
138
1.68
1.89
1
750 CU / 1113 ACS
561
11416 NORTHWEST - 2
SKOKIE 88
138
138
0.06
1113 ACSR
562
11418 NORTHWEST
CROSBY
138
138
0.05
0.09
1
266.8 ACSR
563
11603 GOODINGS GROVE - 1
CRESTWOOD
138
138
11.32
1
1113 ACSR
564
11603 GOODINGS GROVE - 2
CRESTWOOD
138
138
0.05
1113 ACSR
565
11603 GOODINGS GROVE - 3
CRESTWOOD
138
138
0.16
1113 ACSR
566
11605 GOODINGS GROVE
BEDFORD PARK
138
138
18.45
1
900,1113 ACSR
567
11606 GOODINGS GROVE
BEDFORD PARK
138
138
0.71
17.77
1
900 ACSR
568
11609 GOODINGS GROVE - 1
CRESTWOOD
138
138
0.66
10.53
1
1113 ACSR
569
11609 GOODINGS GROVE - 2
CRESTWOOD
138
138
0.24
1113 ACSR
570
11609 GOODINGS GROVE - 3
CRESTWOOD
138
138
0.04
1113 ACSR
571
11701 PROSPECT HTS - 1
DES PLAINES 46
138
138
0.30
3.90
1
1113 ACSR
572
11701 PROSPECT HTS - 2
DES PLAINES 46
138
138
0.23
0.35
1113 ACSR
573
11701 PROSPECT HTS - 3
DES PLAINES 46
138
138
0.11
1113 ACSR
574
11702 PROSPECT HTS - 1
DES PLAINES 46
138
138
0.25
0.35
1
1113 ACSR
575
11702 PROSPECT HTS - 2
DES PLAINES 46
138
138
0.63
3.66
1113 ACSR
576
11702 PROSPECT HTS - 3
DES PLAINES 46
138
138
0.09
1113 ACSR
577
11704 PROSPECT HEIGHTS - 1
APTAKISIC
138
138
0.13
5.41
1
1113 ACSR
578
11704 PROSPECT HEIGHTS - 2
APTAKISIC
138
138
0.22
1113 ACSR
579
11708 PROSPECT HEIGHTS - 1
APTAKISIC
138
138
0.30
5.46
1
1113 ACSR
580
11708 PROSPECT HEIGHTS - 2
APTAKISIC
138
138
0.10
0.03
266.8, 636, 1113A
581
11902 LANCASTER - 1
MARYLAND
138
138
15.89
4.13
1
1113 ACSR
582
11902 LANCASTER - 2
MARYLAND
138
138
1.25
0.69
1113 ACSR
583
11902 LANCASTER - 3
MARYLAND
138
138
0.10
1.01
1113 ACSR,
584
11904 LANCASTER - 1
ECOGROVE WIND FARM
138
138
0.47
1
636, 1113 ACSR
585
11904 LANCASTER - 2
ECOGROVE WIND FARM
138
138
9.46
636, 1113 ACSR
586
11904 LANCASTER - 3
ECOGROVE WIND FARM
138
138
2.24
636 ACSR
587
11904 TAP
FREEPORT
138
138
1.13
266.8, 636, 1113A
588
12007 LOMBARD - 1
ELMHURST
138
138
8.14
1
1113 ACSR
589
12007 LOMBARD - 2
ELMHURST
138
138
0.06
1113 ACSR
590
12008 LOMBARD - 1
ELMHURST
138
138
0.10
8.16
1
900,1113 ACSR
591
12008 LOMBARD - 2
ELMHURST
138
138
0.11
1113 ACSR
592
12015 LOMBARD - 1
ITASCA
138
138
8.12
1
1113 ACSR
593
12015 LOMBARD - 2
ITASCA
138
138
0.09
1113 ACSR
594
12016 LOMBARD - 1
ITASCA
138
138
0.58
7.45
1
1113 ACSR
595
12016 LOMBARD - 2
ITASCA
138
138
0.10
1113 ACSR
596
12016 LOMBARD - 3
ITASCA
138
138
0.29
1113 ACSR
597
12204 BELVEDERE - 1
PLEASANT VALLEY
138
138
22.72
1
1113 ACSR, 664.8A
598
12204 BELVEDERE - 2
PLEASANT VALLEY
138
138
0.63
664.8ACSS/TW
599
12204 TAP
MARENGO
138
138
1.17
477, 1113 ACSR, 6
600
12205 BELVIDERE - 1
WOODSTOCK
138
138
0.21
21.26
1
1113
601
12205 BELVIDERE - 2
WOODSTOCK
138
138
2.71
2-556.5 ACSR,1113
602
12205 TAP
MARENGO
138
138
1.22
477 ACSR
603
12411 MARYLAND - 1
DIXON
138
138
1.45
1
3/0 CO
604
12411 MARYLAND - 2
DIXON
138
138
11.32
1113 ACSR
605
12411 MARYLAND - 3
DIXON
138
138
2.73
3/0 CO
606
12411 TAP
STERLING
138
138
14.38
1113 ACS
607
13219 GARDEN PLAIN
I.S.P.C.O.
138
138
4.52
1
477 ACSR
608
13304 ROCK FALLS
SCHAUFF ROAD
138
138
11.09
2-556.5, 2156ACSR
609
13501 ELMHURST - 1
BELLWOOD
138
138
0.19
5.31
1
900,1113 ACSR
610
13501 ELMHURST - 2
BELLWOOD
138
138
0.07
900,1113 ACSR
611
13501 ELMHURST - 3
BELLWOOD
138
138
0.07
900,1113 ACSR
612
13502 ELMHURST - 1
BELLWOOD
138
138
0.15
5.29
1
900,1113 ACSR
613
13502 ELMHURST - 2
BELLWOOD
138
138
0.11
900,1113 ACSR
614
13502 ELMHURST - 3
BELLWOOD
138
138
0.05
900,1113 ACSR
615
13503 ELMHURST - 1
NORTHLAKE
138
138
0.30
0.42
1
900,1113 ACSR
616
13503 ELMHURST - 2
NORTHLAKE
138
138
0.16
900 ACSR
617
13504 ELMHURST - 1
FRANKLIN PARK
138
138
0.13
0.40
1
1113 ACSR
618
13504 ELMHURST - 2
FRANKLIN PARK
138
138
1.77
0.14
1113 ACSR
619
13504 ELMHURST - 3
FRANKLIN PARK
138
138
0.12
1113 ACSR
620
13510 ELMHURST - 1
FRANKLIN PARK
138
138
0.10
0.46
1
900,1113 ACSR
621
13510 ELMHURST - 2
FRANKLIN PARK
138
138
0.03
1.77
1113 ACSR
622
13510 ELMHURST - 3
FRANKLIN PARK
138
138
0.22
1113 ACSR
623
13803 STATE LINE
NIPSCO
138
138
0.19
1
900,1113 ACSR
624
13805 SILVER LAKE - 1
SW TIE L-18513
138
138
0.23
4.00
1
1113,2156 ACSR
625
13805 SILVER LAKE - 2
SW TIE L-18513
138
138
0.32
7.06
1277.2 ACSR
626
13805 SILVER LAKE - 3
SW TIE L-18513
138
138
0.11
1113 ACSR
627
13805 SILVER LAKE - 4
SW TIE L-18513
138
138
0.22
1113 ACSR
628
13806 SILVER LAKE - 1
SW TIE L-18512
138
138
0.21
3.91
1
1277.2 ACAR, 477,
629
13806 SILVER LAKE - 2
SW TIE L-18512
138
138
0.36
7.05
1277.2 ACAR
630
13806 SILVER LAKE - 3
SW TIE L-18513
138
138
0.18
477,1113 ACSR
631
13806 SILVER LAKE - 4
SW TIE L-18513
138
138
0.22
477,1113 ACSR
632
13808 SILVER LAKE - 1
CRYSTAL LAKE
138
138
0.09
2.58
1
1113 ACSR
633
13808 SILVER LAKE - 2
CRYSTAL LAKE
138
138
0.07
1113 ACSR
634
13809 SILVER LAKE - 1
PLEASANT VALLEY
138
138
2.39
7.33
1
477,1113 ACSR
635
13809 SILVER LAKE - 2
PLEASANT VALLEY
138
138
0.14
1113 ACSR
636
14101 PLEASANT VALLEY - 1
CRYSTAL LAKE
138
138
0.01
6.77
1
477,1113 ACSR
637
14101 PLEASANT VALLEY - 2
CRYSTAL LAKE
138
138
0.05
0.12
477,1113 ACSR
638
14101 PLEASANT VALLEY - 3
CRYSTAL LAKE
138
138
0.09
477,1113 ACSR
639
14101 PLEASANT VALLEY - 4
CRYSTAL LAKE
138
138
0.08
477,1113 ACSR
640
14102 PLEASANT VALLEY
TOLLWAY
138
138
26.47
0.96
1
1113 ACSR, 2-556R
641
14103 PLEASANT VALLEY
TOLLWAY
138
138
0.26
27.20
1
1113 ACSR, 2-556R
642
14106 PLEASANT VALLEY - 1
WOODSTOCK
138
138
3.06
1
664.8 ACSS/TW
643
14106 PLEASANT VALLEY - 2
WOODSTOCK
138
138
0.16
0.51
1113 ACSR, 664.8
644
14302 WOLFS - 1
PLANO
138
138
0.14
1
1113 ACSR
645
14302 WOLFS - 2
PLANO
138
138
6.35
477,1113
646
14302 WOLFS - 3
PLANO
138
138
7.00
1113,2156 ACSR
647
14302 TAP
ROW BREAKER AT
138
138
0.02
1113 ACSR
648
14304 WOLFS - 1
PLANO
138
138
0.14
1
1113ACSR
649
14304 WOLFS - 2
PLANO
138
138
6.35
477,1113
650
14304 WOLFS - 3
PLANO
138
138
0.21
6.79
1113, 2156 ACSR
651
14403 WAYNE - 1
AURORA E.C.
138
138
0.01
12.04
1
1113 ACSR
652
14403 WAYNE - 2
AURORA E.C.
138
138
0.30
0.16
1113 ACSR
653
14405 WAYNE - 1
AURORA E.C.
138
138
0.21
11.76
1
1113 ACSR
654
14405 WAYNE - 2
AURORA E.C.
138
138
0.41
0.17
1113 ACSR
655
14609 SANDWICH - 1
PLANO
138
138
0.12
1
1113 ACSR
656
14609 SANDWICH - 2
PLANO
138
138
9.58
1113 ACSR
657
15001 CALUMET
RIVER E.C.
138
138
0.30
1.86
1
636,1113 ACSR
658
15002 CALUMET
RIVER E.C.
138
138
0.34
1.87
1
477,1113 ACSR
659
15410 LIBERTYVILLE - 1
APTAKISIC
138
138
0.25
9.17
1
1113 ACSR
660
15410 LIBERTYVILLE - 2
APTAKISIC
138
138
0.41
1113 ACSR
661
15417 LIBERTYVILLE - 1
APTAKISIC
138
138
0.54
9.10
1
1113 ACSR
662
15417 LIBERTYVILLE - 2
APTAKISIC
138
138
0.17
0.04
1113 ACSR
663
15507 NELSON - 1
DIXON 107
138
138
0.48
9.11
1
477,1113 ACSR
664
15507 NELSON - 2
DIXON 107
138
138
0.78
477,1113 ACSR
665
15508 NELSON - 1
DIXON 107
138
138
9.12
0.47
1
477,1113 ACSR
666
15508 NELSON - 2
DIXON 107
138
138
0.78
477,1113 ACSR
667
15509 NELSON
ROCK FALLS
138
138
0.25
2.62
1
1113 ACSR
668
15511 NELSON - 1
DIXON R/W
138
138
0.71
1
1113 ACSR
669
15511 NELSON - 2
DIXON R/W
138
138
4.97
1113 ACSR
670
15511 TAP
STERLING
138
138
0.05
312.8 AAAC / 1113
671
15518 NELSON - 1
GARDEN PLAIN
138
138
0.22
2.62
1
266.8,477,1113 AC
672
15518 NELSON - 2
GARDEN PLAIN
138
138
18.21
1113 AA / 477 ACS
673
15518 NELSON - 3
GARDEN PLAIN
138
138
7.88
266.8 ACSR
674
15518 TAP
ROCK FALLS
138
138
0.04
1113 ACSR
675
15621 CHERRY VALLEY - 1
DIXON
138
138
1.15
1
1113 ACSR
676
15621 CHERRY VALLEY - 2
DIXON
138
138
0.03
1113 ACSR
677
15621 CHERRY VALLEY - 3
DIXON
138
138
16.81
1113 ACSR
678
15622 CHERRY VALLEY - 1
SABROOKE
138
138
0.07
0.36
1
1113 ACSR
679
15622 CHERRY VALLEY - 2
SABROOKE
138
138
7.16
1113 ACSR
680
15623 CHERRY VALLEY - 1
BELVIDERE
138
138
3.85
4.74
1
1277.2 ACAR / 215
681
15623 CHERRY VALLEY - 2
BELVIDERE
138
138
0.16
1277.2 ACAR / 215
682
15624 CHERRY VALLEY - 1
BELVIDERE
138
138
0.34
1.17
1
1113 ACSR
683
15624 CHERRY VALLEY - 2
BELVIDERE
138
138
6.53
1113 ACSR
684
15624 CHERRY VALLEY - 3
BELVIDERE
138
138
0.10
1113 ACSR
685
15625 CHERRY VALLEY - 1
WEMPLETOWN
138
138
0.44
22.39
1
1113,2156 ACSR
686
15625 CHERRY VALLEY - 2
WEMPLETOWN
138
138
0.10
2.60
1113,2-556.5 ASCR
687
15625 CHERRY VALLEY - 3
WEMPLETOWN
138
138
0.06
1113 ACSR
688
15626 CHERRY VALLEY - 1
SABROOKE
138
138
0.10
0.36
1
1113 ACSR
689
15626 CHERRY VALLEY - 2
SABROOKE
138
138
7.15
1113 ACSR
690
15627 CHERRY VALLEY - 1
GLIDDEN
138
138
21.00
0.98
1
1113,2156 ACSR
691
15627 CHERRY VALLEY - 2
GLIDDEN
138
138
7.15
1113 ACSR
692
15912 NORTHBROOK 159 - 1
HIGHLAND PARK
138
138
4.02
1
1113 ACSR
693
15912 NORTHBROOK 159 - 2
HIGHLAND PARK
138
138
0.35
0.35
1113 ACSR,2156 ACSR
694
15913 NORTHBROOK 159 - 1
HIGHLAND PARK
138
138
4.12
1
1113 ACSR
695
15913 NORTHBROOK 159 - 2
HIGHLAND PARK
138
138
0.73
1113,2156 ACSR
696
16901 MCGIRR ROAD - 1
SHADY OAKS
138
138
11.29
1
1113 ACSR
697
16901 MCGIRR ROAD - 2
SHADY OAKS
138
138
0.09
1113 ACSR
698
16901 TAP
MENDOTA HILLS
138
138
0.04
1113 ACSR
699
16914 MCGIRR ROAD - 1
STEWARD
138
138
0.22
0.01
1
1113 ACSR
700
16914 MCGIRR ROAD - 2
STEWARD
138
138
1.21
1113 ACSR
701
16914 TAP - 1
RITCHIE ROAD
138
138
1.08
266.8 ACSR
702
16914 TAP - 2
RITCHIE ROAD
138
138
4.19
556.5, 1113 ACSR, T2-556.5 ACSR
703
17008 HARBOR
UNIVERSITY
138
138
0.50
5.45
1
1113,2156 ACSR
704
17113 SABROOKE - 1
WEMPLETOWN
138
138
3.69
0.34
1
1113 ACSR
705
17113 SABROOKE - 2
WEMPLETOWN
138
138
2.95
3.71
1113 ACSR
706
17113 SABROOKE - 3
WEMPLETOWN
138
138
0.33
1113 ACSR
707
17113 SABROOKE - 4
WEMPLETOWN
138
138
0.20
1
1113 ACSR
708
17121 WEMPLETOWN - 1
LANCASTER
138
138
1.03
1
1113 ACSR
709
17121 WEMPLETOWN - 2
LANCASTER
138
138
22.17
477,1113 ACSR
710
17712 BURNHAM - 1
CHICAGO HTS
138
138
0.56
1
1113 ACSR
711
17712 BURNHAM - 2
CHICAGO HTS
138
138
9.42
1113 ACSR
712
17713 BURNHAM - 1
WILDWOOD
138
138
5.05
1
900,1113 ACSR
713
17713 BURNHAM - 2
WILDWOOD
138
138
0.40
1113 ACSR
714
17714 BURNHAM - 1
WILDWOOD
138
138
5.13
1
900,1113 ACSR
715
17714 BURNHAM - 2
WILDWOOD
138
138
0.13
0.13
1113 ACSR
716
17714 TAP
HEGEWISCH
138
138
0.33
1.89
1113 ACSR
717
17715 BURNHAM - 1
TOWER AUTOMOTIVE
138
138
2.27
1
1113 ACSR
718
17715 BURNHAM - 2
TOWER AUTOMOTIVE
138
138
0.36
0.08
1113 ACSR
719
17903 BLOOM
MATTESON
138
138
6.07
1
1113 ACSR
720
17904 BLOOM
MATTESON
138
138
0.25
5.82
1
1113 ACSR
721
18512 TOLLWAY
SW TIE L-13806
138
138
2.80
1
1277.2 ACAR /111
722
18512 TAP
ROCKY ROAD E.C.
138
138
0.01
1277.2 ACAR
723
18513 TOLLWAY
SW TIE L-13805
138
138
0.58
2.24
1
1277.2 ACAR / 111
724
18513 TAP
ROCKY ROAD E.C.
138
138
0.03
1113 ACSR
725
18706 SCHAUFF ROAD - 1
KEEMIN (AMEREN)
138
138
0.07
1
726
18706 SCHAUFF ROAD - 2
KEEMIN (AMEREN)
138
138
24.88
477 ACSR
727
18618 STEWARD - 1
TWOMBLY ROAD
138
138
11.26
1
556.5 ACSR
728
18618 STEWARD - 2
TWOMBLY ROAD
138
138
0.10
556.5 ACSR
729
18623 STEWARD
HAUMESSER ROAD
138
138
7.21
1
1113 ACSR, 664.8A
730
19414 SABROOKE - 1
LANCASTER
138
138
2.35
1
636,1113 ACSR
731
19414 SABROOKE - 2
LANCASTER
138
138
6.95
1113 ACSR
732
19414 SABROOKE - 3
LANCASTER
138
138
21.14
1113 ACSR
733
28201 ZION TDC 282 - 1
IL-WI STATE LINE
138
138
0.10
1.79
1
1113 ACSR
734
28201 ZION TDC 282 - 2
IL-WI STATE LINE
138
138
0.25
0.14
1113 ACSR
735
28201 ZION TDC 282 - 3
IL-WI STATE LINE
138
138
1.79
477 ACSR
736
52517 NORMANTOWN
BOLINGBROOK
138
138
0.16
2.81
1
737
138KV LINES
138kV LINES
738
0702 ILL-IND STATE LINE
WASHINGTON PARK
138
138
8.44
1
800 MM2 XLPE
739
0705 ILL-IND STATE LINE
WASHINGTON PARK
138
138
9.75
800 MM2 XLPE
740
1106 QUARY
STATE
138
138
2.27
1200 MM2 XLPE / 2
741
1106 FISK
TERMINAL
138
138
0.15
1600 kcmil XLPE
742
1108 QUARY
STATE
138
138
2.26
1200 MM2 XLPE
743
1110 FISK
DEKOVEN
138
138
2.16
1
1600 MM2 XLPE
744
1111 FISK
DEKOVEN
138
138
2.28
1
1600 MM2 XLPE
745
1306 RIDGELAND
LEXTENSION PT
138
138
0.31
1600 MM2 XLPE
746
1317 CRAWFORD
FISK
138
138
4.46
1
2500 HPFF
747
1318 CRAWFORD
FISK
138
138
4.49
1
2500 HPFF
748
1320 CRAWFORD
JEFFERSON
138
138
6.93
1
800 MM2 XLPE
749
1322 CRAWFORD
HAYFORD
138
138
0.34
1600 MM2 XLPE
750
1324 CRAWFORD
HAYFORD
138
138
0.33
1600 MM2 XLPE
751
1326 CRAWFORD
JEFFERSON
138
138
6.72
1
800 MM2 XLPE
752
3610 DEKOVEN
MADISON
138
138
1.07
1
1600 MM2 XLPE
753
3611 DEKOVEN
MADISON
138
138
1.07
1
1600 MM2 XLPE
754
3701Y NATOMA
GALEWOOD
138
138
0.37
1
250 kcmil HPFF
755
3702Y NATOMA
GALEWOOD
138
138
0.43
1
350 kcmil HPFF
756
3703Y NATOMA
GALEWOOD
138
138
0.37
1
250 kcmil HPFF
757
3704Y NATOMA
GALEWOOD
138
138
0.37
1
250 kcmil HPFF
758
3710 FRANKLIN PARK
NATOMA
138
138
5.46
1
2000 kcmil HPFF
759
3705 NATOMA
FRANKLIN PARK
138
138
6.09
1
2000 kcmil HPFF
760
3706 NATOMA
HIGGINS
138
138
4.56
1
2000 kcmil HPFF
761
3707 NATOMA
NORRIDGE
138
138
4.56
1
2000 kcmil HPFF
762
3709 NATOMA
OAK PARK
138
138
3.14
1
2000 kcmil HPFF
763
4522 FISK
JEFFERSON
138
138
2.14
1
2500 kcmil HPFF
764
4523 FISK
JEFFERSON
138
138
2.13
1
2500 kcmil HPFF
765
4525 JEFFERSON
GRAND
138
138
1.94
1
1600 MM2 XLPE
766
4527 JEFFERSON
GRAND
138
138
1.87
1
1600 MM2 XLPE
767
4018 DIVERSEY
CROSBY
138
138
2.59
1
2500 kcmil HPFF
768
4607 DESPLAINES
HIGGINS
138
138
7.57
1
2000 kcmil HPFF
769
5105X RIDGELAND
TERMINAL C
138
138
0.24
1600 MM2 XLPE
770
5105Y RIDGELAND
TERMINAL C
138
138
0.17
1600 MM2 XLPE
771
5107X MCCOOK
TERMINAL O
138
138
0.08
1600 MM2 XLPE
772
5107Y MCCOOK
TERMINAL Q
138
138
0.08
1600 MM2 XLPE
773
5810 MADISON
GRAND
138
138
1.17
1
1600 MM2 XLPE
774
5811 MADISON
GRAND
138
138
1.17
1
1600 MM2 XLPE
775
5825 GRAND
CROSBY
138
138
1.05
1
1600 MM2 XLPE
776
5826 GRAND
WEST LOOP
138
138
1.50
1
1600 MM2 XLPE
777
5827 GRAND
CROSBY
138
138
0.94
1
1600 MM2 XLPE
778
5828 GRAND
WEST LOOP
138
138
1.40
1
1600 MM2 XLPE
779
8221 CROSBY
ROCKWELL
138
138
1.95
1600 MM2 XLPE
780
8223 CROSBY
ROCKWELL
138
138
1.95
1600 MM2 XLPE
781
11411 NORTHWEST
DEVON
138
138
5.62
1
2000 kcmil HPFF
782
11412 NORTHWEST
NATOMA
138
138
6.45
1
2000 kcmil HPFF
783
11413 NORTHWEST
DIVERSEY
138
138
1.86
2000 kcmil HPFF,2
784
11416 NORTHWEST
DEVON
138
138
5.85
800 MM2 XLPE
785
11417 NORTHWEST
NATOMA
138
138
6.08
1
2000 kcmil HPFF
786
11418 ADDISON RIVER
DIVERSEY
138
138
1.70
2000 kcmil HPFF
787
13503 NORTHLAKE
FRANKLIN PARK
138
138
1.54
2000 kcmil HPFF
788
13701 WASHINGTON PARK
JEFFERSON
138
138
8.25
1
800 MM2 XLPE
789
13701 JEFFERSON
GRENSHAW
138
138
0.52
2500 kcmil HPFF
790
14807 WEST LOOP
CLYBOURN
138
138
1.55
1
1600 mm2 XLPE
791
14818 WEST LOOP
DIVERSEY
138
138
3.24
1
1600 MM2 XLPE
792
14826 WEST LOOP
CROSBY
138
138
0.55
1
1600 MM2 XLPE
793
14828 WEST LOOP
CROSBY
138
138
0.65
1
1600 MM2 XLPE
794
15301 TAYLOR
GRENSHAW
138
138
0.20
1
1600 MM2 XLPE
795
15302 TAYLOR
JEFFERSON
138
138
0.91
1
2000 kcmil HPFF
796
15303 TAYLOR
JEFFERSON
138
138
0.50
1
2500 kcmil HPFF
797
15310 TAYLOR
GRENSHAW
138
138
0.19
1
1600 MM2 XLPE
798
15315 LASALLE
STATE
138
138
0.91
1
1200 MM2 XPLE
799
15315 TAYLOR
LASALLE
138
138
0.82
2500 kcmil HPFF
800
15316 TAYLOR
LASALLE
138
138
0.77
1
2500 kcmil HPFF
801
15317 TAYLOR
LASALLE
138
138
0.76
1
2500 kcmil HPFF
802
15317 LASALLE
STATE
138
138
0.91
1200 MM2 XPLE
803
15318 TAYLOR
LASALLE
138
138
0.78
1
2500 kcmil HPFF
804
17008 61ST STREET
UNIVERSITY
138
138
2.45
2000 kcmil HPFF
805
17401 UNIVERSITY
GRENSHAW
138
138
6.49
1
2000 kcmil HPFF
806
17404 UNIVERSITY
WASHINGTON PARK
138
138
2.20
1
2000 kcmil HPFF
807
19209 RIDGELAND
OAK PARK
138
138
5.35
1
2000 kcmil HPFF
808
19801 DESPLAINES
NORRIDGE
138
138
4.67
1
2000 kcmil HPFF
809
9203 MCLEAN - 1
BROKAW (AMEREN)
345
345
0.09
1
2-1277 ACAR
810
9203 MCLEAN - 2
BROKAW (AMEREN)
345
345
20.71
2-1277 ACAR
811
9806 NEVADA - 1
GOODINGS GROVE
345
345
0.17
0.39
1
2-1277 ACAR, 2156
812
9806 NEVADA - 2
GOODINGS GROVE
345
345
0.18
55.68
2-1277 ACAR, 2338
813
7405 KEWANEE - 1
SCHAUFF  ROAD
138
138
0.06
1
1590ACSR
814
7405 KEWANEE - 2
SCHAUFF  ROAD
138
138
31.70
477ACSR
815
18702 SCHAUFF ROAD
ROCK FALLS
138
138
0.12
11.01
1
2-556.5, 1590ACSR
816
8001 PONTIAC MIDPOINT
MCLEAN
345
345
0.06
817
8302 GLIDDEN
CREGO ROAD
138
138
3.63
1
2-556.5 ACSR, 2156 ACSR
818
8309 GLIDDEN
CREGO ROAD
138
138
5.09
1
2-556.5, 2156 ACSR
819
15515 NELSON
SCHAUFF ROAD
138
138
17.55
1
2-556.5, 1590 ACSR
820
18407 ELK GROVE - 1
TONNE
138
138
0.16
1
1113 ACSR
821
18407 ELK GROVE - 2
TONNE
138
138
0.09
2.39
1113 ACSR
822
18408 ELK GROVE - 1
TONNE
138
138
0.24
1
1113 ACSR
823
18408 ELK GROVE - 2
TONNE
138
138
2.39
1113 ACSR
824
1 RITCHIE ROAD
CARON ROAD
138
138
1.45
1
556.5, T2-556.5 ACSR
825
93913 MULBERRY - 1
MOLE CREEK
345
345
0.47
1
2-1277 ACAR, 2156 ACSR
826
93913 MULBERRY - 2
MOLE CREEK
345
345
57.28
2-1277 ACAR, 2338 ACAR
827
93915 MULBERRY - 1
TAZEWELL (CLICO)
345
345
0.16
0.18
1
2156 ACSR
828
93915 MULBERRY - 2
TAZEWELL (CLICO)
345
345
0.17
94.27
2-1277 ACAR, 2338 ACAR
829
59306 WILLOW SPRINGS - 1
BURR RIDGE
138
138
0.07
5.14
1
1113 ACSR
830
59306 WILLOW SPRINGS - 2
BURR RIDGE
138
138
0.12
0.11
1113 ACSR
831
59306 WILLOW SPRINGS - 3
BURR RIDGE
138
138
0.05
1113 ACSR
832
8604 DAVIS CREEK - 1
BRADLEY
138
138
5.48
0.94
1
1113, T2-556.5, ACSR
833
8604 DAVIS CREEK - 2
BRADLEY
138
138
0.00
0.28
1113 ACSR
834
8604 DAVIS CREEK - 3
BRADLEY
138
138
0.08
1113 ACSR
835
7404 KEWANEE - 1
PUTNAM (AMEREN)
138
138
31.90
1
477 ACSR
836
7404 KEWANEE - 2
PUTNAM (AMEREN)
138
138
0.14
0.29
2-556.5 ACSR
837
98105 CRESCENT RIDGE - 1
CORBIN (AMEREN)
138
138
0.28
1
477,1113 ACSR
838
98105 CRESCENT RIDGE - 2
CORBIN (AMEREN)
138
138
27.96
477 ACSR
839
19906 KENSINGTON
CSL BEHRING
138
138
4.77
1
1113 ACSR
840
19907 KENSINGTON
CSL BEHRING
138
138
0.13
4.64
1
1113 ACSR
841
90907 DEER CREEK - 1
BROKAW (AMEREN)
345
345
7.49
1
2-1277 ACAR
842
90907 DEER CREEK - 2
BROKAW (AMEREN)
345
345
13.04
2-1277 ACAR
843
90907 DEER CREEK - 3
BROKAW (AMEREN)
345
345
1.27
2-1277 ACAR
36 TOTAL
3,052
1,956
392
131,588,062
2,741,283,286
2,872,871,348


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: TransmissionLineStartPoint
The statistical data on pages 422.1 through 423.25 excludes High Voltage Distribution lines consistent with the Plant in Service balance reported on pages 422 and 423, columns (j), (k) and (l), rows 2, 4 and 6.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
TRANSMISSION LINES ADDED DURING YEAR
  1. Report below the information called for concerning Transmission lines added or altered during the year. It is not necessary to report minor revisions of lines.
  2. Provide separate subheadings for overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (l) to (o), it is permissible to report in these columns the costs. Designate, however, if estimated amounts are reported. Include costs of Clearing Land and Rights-of-Way, and Roads and Trails, in column (l) with appropriate footnote, and costs of Underground Conduit in column (m).
  3. If design voltage differs from operating voltage, indicate such fact by footnote; also where line is other than 60 cycle, 3 phase, indicate such other characteristic.
LINE DESIGNATION SUPPORTING STRUCTURE CIRCUITS PER STRUCTURE CONDUCTORS LINE COST
Line No.
TransmissionLineStartPoint
From
TransmissionLineEndPoint
To
LengthOfTransmissionLineAdded
Line Length in Miles
SupportingStructureOfTransmissionLineType
Type
AverageNumberOfSupportingStructuresOfTransmissionLinePerMiles
Average Number per Miles
NumberOfTransmissionCircuitsPerStructurePresent
Present
NumberOfTransmissionCircuitsPerStructureUltimate
Ultimate
ConductorSize
Size
ConductorSpecification
Specification
ConductorConfigurationAndSpacing
Configuration and Spacing
OperatingVoltageOfTransmissionLine
Voltage KV (Operating)
CostOfLandAndLandRightsTransmissionLinesAdded
Land and Land Rights
CostOfPolesTowersAndFixturesTransmissionLinesAdded
Poles, Towers and Fixtures
CostOfConductorsAndDevicesTransmissionLinesAdded
Conductors and Devices
Asset Retire. Costs
CostOfTransmissionLinesAdded
Total
SupportingStructureConstructionType
Construction
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
(k)
(l)
(m)
(n)
(o)
(p)
(q)
1
138 kV Overhead
2
Line Sections Installed
3
7713 MAZON
CORBIN (AMEREN)
0.15
9
2
2
Single Conductor
138
Overground
4
98105 CRESCENT RIDGE
CORBIN (AMEREN)
0.20
9
2
2
Single Conductor
138
Overground
5
6101 STREATOR
PUTNAM (AMEREN)
0.40
7
2
2
Single Conductor
138
Overground
6
7404 KEWANEE
PUTNAM (AMEREN)
0.43
7
2
2
Single Conductor
138
Overground
7
19906 KENSINGTON
CSL BEHRING
0.10
8
2
2
Single Conductor
138
Overground
8
19907 KENSINGTON
CSL BEHRING
0.10
8
2
2
Single Conductor
138
Overground
9
Total - 1
9,867,667
4,042,673
13,910,340
10
345 kV Overhead
11
90907 DEER CREEK
BROKAW (AMEREN)
0.06
4
1
1
Single Conductor
345
Overground
12
Total - 2
225
4
229
44
TOTAL
1.44
52
13
13
9,867,442
4,042,669
13,910,111


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
SUBSTATIONS
  1. Report below the information called for concerning substations of the respondent as of the end of the year.
  2. Substations which serve only one industrial or street railway customer should not be listed below.
  3. Substations with capacities of Less than 10 MVA except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown.
  4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (f).
  5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity.
  6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company.
Character of Substation VOLTAGE (In MVa) Conversion Apparatus and Special Equipment
Line No.
SubstationNameAndLocation
Name and Location of Substation
(a)
SubstationCharacterDescription
Transmission or Distribution
(b)
SubstationCharacterAttendedOrUnattended
Attended or Unattended
(b-1)
PrimaryVoltageLevel
Primary Voltage (In MVa)
(c)
SecondaryVoltageLevel
Secondary Voltage (In MVa)
(d)
TertiaryVoltageLevel
Tertiary Voltage (In MVa)
(e)
SubstationInServiceCapacity
Capacity of Substation (In Service) (In MVa)
(f)
NumberOfTransformersInService
Number of Transformers In Service
(g)
Number of Spare Transformers
(h)
ConversionApparatusAndSpecialEquipmentType
Type of Equipment
(i)
NumberOfConversionApparatusAndSpecialEquipmentUnits
Number of Units
(j)
CapacityOfConversionApparatusAndSpecialEquipment
Total Capacity (In MVa)
(k)
1
CHICAGO (OVER 10 MVA)
2
89-BEVERLY
Distribution
Unattended
138.00
12.50
132
4
3
150-CALUMET-1
Distribution
Attended
138.00
12.50
300
4
4
150-CALUMET-2
Distribution
Attended
138.00
69.00
120
3
5
54-CLYBOURN
Distribution
Unattended
138.00
12.50
200
4
6
30-COLUMBUS PARK-1
Distribution
Unattended
69.00
12.50
219
6
7
13-CRAWFORD-1
Transmission
Unattended
345.00
138.00
34.00
1200
4
8
13-CRAWFORD-2
Distribution
Unattended
138.00
12.50
400
8
9
82-CROSBY
Distribution
Unattended
138.00
12.50
200
4
10
814-DAMEN
Distribution
Unattended
138.00
12.50
80
2
11
87-DEARBORN
Distribution
Unattended
69.00
12.50
160
4
12
110-DEVON
Distribution
Unattended
138.00
12.50
160
4
13
40-DIVERSEY
Distribution
Unattended
138.00
12.50
200
4
14
11-FISK-1
Transmission
Unattended
345.00
138.00
34.00
600
2
15
11-FISK-2
Distribution
Unattended
138.00
12.50
200
3
16
104-FORD CITY
Distribution
Unattended
138.00
12.50
100
3
17
31-GALEWOOD-1
Distribution
Unattended
138.00
12.50
160
4
18
90-DEKOVEN
Distribution
Unattended
138.00
69.00
400
2
19
32-HANSON PARK-1
Distribution
Unattended
138.00
12.50
160
4
20
33-HAYFORD
Distribution
Unattended
138.00
12.50
120
4
21
55-HEGEWISCH
Distribution
Unattended
138.00
12.50
146
4
22
71-HIGGINS
Distribution
Unattended
138.00
12.50
160
4
23
38-HUMBOLDT PARK-1
Distribution
Unattended
138.00
12.50
200
4
24
745-I.C.AIR RIGHTS
Distribution
Unattended
138.00
12.50
200
4
25
45-JEFFERSON-1
Distribution
Unattended
138.00
12.50
250
5
26
45-JEFFERSON-2
Distribution
Unattended
138.00
69.00
12.50
800
12
27
34-KINGSBURY
Distribution
Unattended
138.00
12.50
200
4
28
68-LA SALLE
Distribution
Unattended
138.00
12.50
200
4
29
36-MADISON
Distribution
Unattended
138.00
12.50
250
5
30
714-MEDICAL CENTER
Distribution
Unattended
138.00
12.50
200
4
31
37-NATOMA
Distribution
Unattended
138.00
12.50
100
2
32
648-NORRIDGE
Distribution
Unattended
138.00
12.50
160
4
33
114-NORTHWEST-1
Distribution
Unattended
138.00
12.50
12.50
375
5
34
114-NORTHWEST-2
Distribution
Unattended
138.00
12.50
160
4
35
65-OHIO
Distribution
Unattended
138.00
12.50
250
5
36
785-ONTARIO
Distribution
Unattended
138.00
12.50
200
4
37
49-PLYMOUTH COURT
Distribution
Unattended
69.00
12.50
160
4
38
39-PORTAGE
Distribution
Unattended
138.00
12.50
268
8
39
840-QUARRY
Distribution
Unattended
138.00
12.50
200
4
40
84-ROSEHILL
Distribution
Unattended
138.00
12.50
200
4
41
41-ROSELAND
Distribution
Unattended
69.00
12.50
99
3
42
63-SAWYER
Distribution
Unattended
138.00
12.50
132
4
43
784-SEARS
Distribution
Unattended
138.00
12.50
200
4
44
126-STATE
Distribution
Unattended
138.00
12.50
200
4
45
153-TAYLOR
Transmission
Unattended
345.00
138.00
34.00
600
2
46
174-UNIVERSITY
Distribution
Unattended
138.00
12.50
200
4
47
118-WALLACE
Distribution
Unattended
138.00
12.50
106
3
48
137-WASHINGTON PARK
Distribution
Unattended
138.00
12.50
225
3
49
148-WEST LOOP
Transmission
Unattended
345.00
138.00
34.00
600
2
50
43-WILDWOOD-1
Distribution
Unattended
138.00
12.50
66
2
51
X310-ALBANY PARK
Distribution
Unattended
12.50
4.00
22
3
52
Z300-ARCHER
Distribution
Unattended
12.50
4.00
11
3
53
Y310-AUSTIN
Distribution
Unattended
12.50
4.00
18
3
54
X301-BELMONT
Distribution
Unattended
12.50
4.00
22
3
55
679-BESLEY COURT
Distribution
Unattended
12.50
4.00
25
4
56
Y365-CAMPBELL
Distribution
Unattended
12.50
4.00
24
3
57
798-CARROLL
Distribution
Unattended
12.50
4.00
17
3
58
666-CENTER
Distribution
Unattended
12.50
4.00
15
2
59
X304-CHASE
Distribution
Unattended
34.00
4.00
15
2
60
X381-CORTLAND
Distribution
Unattended
12.50
4.00
22
3
61
750-CRAGIN
Distribution
Unattended
12.50
4.00
26
3
62
Z310-DREXEL
Distribution
Unattended
12.50
4.00
15
3
63
X300-EASTWOOD
Distribution
Unattended
12.50
4.00
24
3
64
Z312-EXCHANGE
Distribution
Unattended
12.50
4.00
15
3
65
31-GALEWOOD-2
Distribution
Unattended
12.50
4.00
15
3
66
834-GRAND CROSSING
Distribution
Unattended
12.50
4.00
30
5
67
894-HARPER
Distribution
Unattended
12.50
4.00
20
3
68
38-HUMBOLDT PARK-2
Distribution
Unattended
12.50
4.00
30
4
69
860-HYDE PARK
Distribution
Unattended
12.50
4.00
20
3
70
674-IRVING PARK
Distribution
Unattended
12.50
4.00
15
2
71
Z314-JUSTINE
Distribution
Unattended
12.50
4.00
15
2
72
793-LARAMIE
Distribution
Unattended
12.50
4.00
22
3
73
603-LAWRENCE
Distribution
Unattended
12.50
4.00
15
2
74
821-MARQUETTE PARK
Distribution
Unattended
12.50
4.00
22
3
75
895-MARSHFIELD
Distribution
Unattended
12.50
4.00
15
2
76
X313-MONTROSE
Distribution
Unattended
12.50
4.00
24
3
77
Z306-NARRAGANSETT
Distribution
Unattended
34.00
12.00
16
2
78
X312-NEWPORT
Distribution
Unattended
12.50
4.00
13
2
79
X315-NEVA #1
Distribution
Unattended
12.50
4.00
12
3
80
687-NORWOOD PARK
Distribution
Unattended
12.5
4
25
4
81
741-PERSHING
Distribution
Unattended
12.5
4
22
3
82
884-PRAIRIE
Distribution
Unattended
12.5
4
13
3
83
X307-ROSEMONT
Distribution
Unattended
34.0
4
15
2
84
626-SCHOOL
Distribution
Unattended
13
4
12
2
85
Z335-SOUTH CHICAGO
Distribution
Unattended
12.5
4
30
4
86
875-THROOP
Distribution
Unattended
12.5
4
18
3
87
X319-UPTOWN
Distribution
Unattended
12.5
4
24
3
88
851-WASHTENAW
Distribution
Unattended
12.5
4
23
3
89
691-WAVELAND
Distribution
Unattended
12.5
4
28
4
90
761-WENDELL
Distribution
Unattended
12.5
4
28
3
91
855-WINDSOR PARK
Distribution
Unattended
12.5
4
23
3
92
X380-WRIGHTWOOD
Distribution
Unattended
12.5
4
23
3
93
Y314-17TH STREET
Distribution
Unattended
12.5
4
23
3
94
Y302-27TH STREET
Distribution
Unattended
12.5
4
15
2
95
Y308-28TH STREET
Distribution
Unattended
12.5
4
23
3
96
871-56TH STREET
Distribution
Unattended
12.5
4
15
2
97
853-62ND STREET
Distribution
Unattended
12.5
4
15
2
98
896-111TH STREET
Distribution
Unattended
12.5
4
12
4
99
X318-MERRIMAC
Distribution
Unattended
12.5
4
11
3
100
TOTAL CHICAGO (OVER 10MVA)
7,991.0
1,488
161
13171
340
101
CHICAGO (UNDER 10 MVA)
102
X315-NEVA #2
Distribution
Unattended
13
4
3
1
103
30-COLUMBUS PARK-2
Distribution
Unattended
12.5
4
6
1
104
Z302-EWING
Distribution
Unattended
12.5
4
8
2
105
32-HANSON PARK-2
Distribution
Unattended
12.5
4
4
1
106
Z305-KEATING
Distribution
Unattended
12.5
4
8
2
107
X311-LEHIGH
Distribution
Unattended
34
4
6
1
108
Z307-NEWCASTLE
Distribution
Unattended
34
12.5
9
1
109
X39-PORTAGE PARK
Distribution
Unattended
12.5
4
3
1
110
X368-SAUGANASH#1
Distribution
Unattended
12.5
4
3
1
111
X368-SAUGANASH#2
Distribution
Unattended
12.5
4
8
2
112
X305-SEMINARY
Distribution
Unattended
12.5
4
7
1
113
43-WILDWOOD-2
Distribution
Unattended
12.5
4
5
1
114
TOTAL CHICAGO (UNDER 10MVA)
193.0
56.5
0
70
15
115
OUTSIDE CHICAGO (OVER 10MVA)
116
240-CARY
Distribution
Unattended
138.00
12.50
80
2
117
569-SUGAR GROVE-1
Distribution
Unattended
138
12.5
80
2
118
101-ITASCA
Distribution
Unattended
138.00
12.50
120
3
119
259-ALGONQUIN
Distribution
Unattended
138.00
12.50
120
3
120
552-ADDISON
Distribution
Unattended
138.00
12.50
73
2
121
160-ALPINE-1
Distribution
Unattended
138.00
12.50
106
3
122
160-ALPINE-2
Distribution
Unattended
138.00
69.00
50
1
123
60-ALSIP-1
Distribution
Unattended
138.00
12.50
146
4
124
60-ALSIP-2
Distribution
Unattended
138.00
34.00
12.50
80
2
125
230-ANTIOCH
Distribution
Unattended
138.00
12.50
80
2
126
109-APTAKISIC
Distribution
Unattended
138.00
12.50
160
4
127
487-ARCHER
Distribution
Unattended
138.00
12.50
80
2
128
268-ARLINGTON
Distribution
Unattended
138.00
12.50
160
4
129
233-BARRINGTON
Distribution
Unattended
138.00
12.50
80
4
130
250-BARRINGTON HILLS
Distribution
Unattended
138.00
12.50
12
1
131
574-BARTLETT
Distribution
Unattended
138.00
12.50
146
4
132
391-ARGYLE
Distribution
Unattended
138.00
12.50
60
2
133
115-BEDFORD PARK-1
Transmission
Unattended
345.00
138.00
34.00
1200
4
134
115-BEDFORD PARK-2
Distribution
Unattended
138.00
34.00
12.50
180
5
135
64-BELLWOOD-1
Distribution
Unattended
138.00
12.50
106
3
136
64-BELLWOOD-2
Distribution
Unattended
138.00
34.00
12.50
240
4
137
416-BELL ROAD
Distribution
Unattended
138.00
12.50
146
4
138
122-BELVIDERE-1
Distribution
Unattended
138.00
34.00
12.50
120
2
139
122-BELVIDERE-2
Distribution
Unattended
138.00
12.50
80
2
140
549-BERKELEY
Distribution
Unattended
138.00
12.50
80
2
141
556-BERWYN-1
Distribution
Unattended
69.00
12.50
80
2
142
387-BLACKHAWK
Distribution
Unattended
138.00
12.50
40
2
143
179-BLOOM-1
Transmission
Unattended
345.00
138.00
34.00
300
1
144
179-BLOOM-2
Distribution
Unattended
138.00
12.50
73
2
145
76-BLUE ISLAND-1
Transmission
Unattended
345.00
138.00
34.00
1200
4
146
76-BLUE ISLAND-2
Distribution
Unattended
138.00
34.00
12.50
120
3
147
76-BLUE ISLAND-3
Distribution
Unattended
138.00
12.50
100
3
148
561-BOLINGBROOK
Distribution
Unattended
138.00
12.50
160
4
149
70-BRADLEY-1
Distribution
Unattended
138.00
34.00
12.50
160
4
150
70-BRADLEY-2
Distribution
Unattended
138.00
12.50
146
4
151
531-BRIDGEVIEW
Distribution
Unattended
138.00
12.50
80
2
152
474-BRIGGS
Distribution
Unattended
138.00
12.50
80
2
153
J19-BRUCE ROAD
Distribution
Unattended
34.00
12.50
16
2
154
237-BUFFALO GROVE
Distribution
Unattended
138.00
12.50
80
2
155
177-BURNHAM
Transmission
Unattended
345.00
138.00
34.00
600
2
156
136-BURR RIDGE
Distribution
Unattended
138.00
12.50
160
4
157
152-BUSSE-1
Distribution
Unattended
138.00
34.00
12.50
120
2
158
152-BUSSE-2
Distribution
Unattended
138.00
12.50
160
4
159
557-BUTTERFIELD
Distribution
Unattended
138.00
13.00
80
2
160
433-CHANNAHON WEST-1
Distribution
Unattended
138.00
12.50
20
1
161
380-CHARLES
Distribution
Unattended
138.00
13.20
73
2
162
156-CHERRY VALLEY
Transmission
Unattended
345.00
138.00
34.00
900
3
163
73-CHICAGO HEIGHTS
Distribution
Unattended
138.00
34.00
12.50
180
3
164
568-CHURCH ROAD
Distribution
Unattended
138.00
12.50
80
2
165
59-CICERO-1
Distribution
Unattended
69.00
12.50
78
3
166
550-CLEARING
Distribution
Unattended
138.00
12.50
113
3
167
23-COLLINS
Transmission
Unattended
765.00
345.00
34.00
1000
3
168
435-COUNTRY CLUB HILLS
Distribution
Unattended
138.00
12.50
120
3
169
461-CRESTWOOD
Distribution
Unattended
138.00
12.50
160
4
170
75-CRYSTAL LAKE-1
Distribution
Unattended
138.00
34.00
12.50
120
3
171
75-CRYSTAL LAKE-2
Distribution
Unattended
138.00
12.50
136
4
172
86-DAVIS CREEK-1
Transmission
Unattended
345.00
138.00
34.00
900
3
173
86-DAVIS CREEK-2
Distribution
Unattended
138.00
12.50
40
1
174
213-DEERFIELD
Distribution
Unattended
138.00
12.50
160
4
175
521-BRISTOL TWP
Distribution
Unattended
138.00
12.50
80
2
176
46-DESPLAINES-1
Transmission
Unattended
345.00
138.00
34.00
1200
4
177
46-DESPLAINES-2
Distribution
Unattended
138.00
34.00
12.50
120
2
178
46-DESPLAINES-3
Distribution
Unattended
138.00
12.50
120
3
179
198-DESPLAINES
Distribution
Unattended
138.00
12.50
139
4
180
107-DIXON
Distribution
Unattended
138.00
34.00
12.50
120
2
181
317-DIXON
Distribution
Unattended
138.00
12.50
50
2
182
580-DOWNERS GROVE
Distribution
Unattended
138.00
12.50
160
4
183
12-DRESDEN-1
Transmission
Unattended
345.00
138.00
34.00
600
2
184
12-DRESDEN-2
Distribution
Unattended
138.00
34.00
12.50
40
1
185
260-DUNDEE
Distribution
Unattended
138.00
12.50
80
2
186
66-EAST FRANKFORT
Transmission
Unattended
345.00
138.00
34.00
300
1
187
389-EAST ROCKFORD
Distribution
Unattended
138.00
12.50
80
2
188
111-ELECTRIC JUNCTION-1
Transmission
Unattended
345.00
138.00
34.00
1200
4
189
111-ELECTRIC JUNCTION-2
Distribution
Unattended
138.00
12.50
80
2
190
111-ELECTRIC JUNCTION-3
Distribution
Unattended
138.00
34.00
12.50
120
2
191
370-ELEROY
Distribution
Unattended
138.00
12.50
40
2
192
570-ELGIN
Distribution
Unattended
138.00
12.50
160
4
193
135-ELMHURST-1
Transmission
Unattended
345.00
138.00
34.00
900
3
194
135-ELMHURST-2
Distribution
Unattended
138.00
12.50
80
2
195
258-ELMWOOD
Distribution
Unattended
138.00
12.50
80
2
196
47-EVANSTON-1
Distribution
Unattended
138.00
34.00
12.50
80
2
197
47-EVANSTON-2
Distribution
Unattended
138.00
12.50
160
4
198
433-CHANNAHON WEST-2
Distribution
Unattended
138.00
34.00
60
1
199
469-EVERGREEN
Distribution
Unattended
138.00
12.50
80
2
200
385-FIFTEENTH ST SUB
Distribution
Unattended
69.00
12.50
25
1
201
165-FORDHAM-1
Distribution
Unattended
138.00
12.50
50
1
202
165-FORDHAM-2
Distribution
Unattended
69.00
12.50
83
2
203
57-FOREST PARK
Distribution
Unattended
69.00
12.50
75
3
204
140-FRANKFORT
Distribution
Unattended
138.00
12.50
80
2
205
78-FRANKLIN PARK-1
Distribution
Unattended
138.00
34.00
12.50
240
4
206
78-FRANKLIN PARK-2
Distribution
Unattended
138.00
12.50
100
3
207
121-FREEPORT-1
Distribution
Unattended
138.00
34.00
12.50
80
2
208
121-FREEPORT-2
Distribution
Unattended
138.00
12.50
40
2
209
581-FRONTENAC
Distribution
Unattended
138.00
12.50
160
4
210
132-GARDEN PLAIN-1
Distribution
Unattended
138.00
34.00
12.50
80
3
211
572-GILBERTS
Distribution
Unattended
138.00
12.50
120
3
212
562-GLENDALE HTS
Distribution
Unattended
138.00
12.50
160
4
213
555-GLEN ELLYN
Distribution
Unattended
138.00
12.50
80
2
214
452-GLENWOOD
Distribution
Unattended
138.00
12.50
100
4
215
83-GLIDDEN-1
Distribution
Unattended
138.00
12.50
80
2
216
83-GLIDDEN-2
Distribution
Unattended
138.00
34.00
12.50
80
2
217
172-GOLF MILL-1
Transmission
Unattended
345.00
138.00
34.00
600
2
218
172-GOLF MILL-2
Distribution
Unattended
138.00
12.50
160
4
219
116-GOODINGS GROVE
Transmission
Unattended
345.00
138.00
34.00
1200
4
220
72-GOOSE LAKE
Distribution
Unattended
138.00
34.00
12.50
80
2
221
560-GRACE
Distribution
Unattended
138.00
12.50
80
2
222
458-GREEN LAKE
Distribution
Unattended
138.00
12.50
80
2
223
294-GURNEE
Distribution
Unattended
138.00
12.50
120
3
224
563-HANOVER TWP
Distribution
Unattended
138.00
12.50
80
2
225
388-HARLEM
Distribution
Unattended
138.00
12.50
100
2
226
384-HARRISON
Distribution
Unattended
69.00
12.50
80
2
227
443-HARVEY
Distribution
Unattended
138.00
12.50
80
2
228
52-HAWTHORNE
Distribution
Unattended
69.00
12.50
77
3
229
48-HIGHLAND PARK-1
Distribution
Unattended
138.00
34.00
12.50
120
3
230
48-HIGHLAND PARK-2
Distribution
Unattended
138.00
12.50
73
2
231
436-HILLCREST
Distribution
Unattended
138.00
12.50
160
4
232
214-HOFFMAN ESTATES
Distribution
Unattended
138.00
12.50
160
4
233
215-HOWARD
Distribution
Unattended
138.00
12.50
80
2
234
101-ITASCA-1
Transmission
Unattended
345.00
138.00
34.00
600
2
235
101-ITASCA-2
Distribution
Unattended
138.00
34.00
180
3
236
456-JOLIET CENTRAL
Distribution
Unattended
138.00
12.50
40
2
237
157-KANKAKEE
Distribution
Unattended
138.00
12.50
80
2
238
134-LAGRANGE PARK
Distribution
Unattended
138.00
12.50
120
3
239
222-LAKE BLUFF
Distribution
Unattended
138.00
12.50
80
2
240
234-LAKEHURST
Distribution
Unattended
138.00
12.50
147
4
241
225-LANDMEIER
Distribution
Unattended
138.00
12.50
80
2
242
446-LANSING
Distribution
Unattended
138.00
12.50
80
2
243
1-LASALLE
Transmission
Attended
345.00
138.00
34.00
300
1
244
166-LEITHTON-1
Distribution
Unattended
138.00
34.00
12.50
40
1
245
166-LEITHTON-2
Distribution
Unattended
138.00
12.50
160
4
246
180-LENA
Distribution
Unattended
138.00
34.00
12.50
80
2
247
154-LIBERTYVILLE-1
Transmission
Unattended
345.00
138.00
34.00
600
2
248
154-LIBERTYVILLE-2
Distribution
Unattended
138.00
12.50
106
3
249
103-LISLE-1
Transmission
Unattended
345.00
138.00
34.00
1200
4
250
103-LISLE-2
Distribution
Unattended
138.00
34.00
12.50
120
3
251
103-LISLE-3
Distribution
Unattended
138.00
12.50
153
4
252
120-LOMBARD-1
Transmission
Attended
345.00
138.00
34.00
600
2
253
120-LOMBARD-2
Distribution
Attended
138.00
34.00
12.50
120
3
254
120-LOMBARD-3
Distribution
Attended
138.00
12.50
120
3
255
409-SOUTH JOLIET
Distribution
Unattended
138.00
34.00
180
3
256
248-LAKE ZURICH
Distribution
Unattended
138.00
12.50
120
3
257
123-MARENGO
Distribution
Unattended
138.00
34.00
12.50
160
4
258
124-MARYLAND
Distribution
Unattended
138.00
34.00
12.50
80
2
259
127-MATTESON-1
Distribution
Unattended
138.00
34.00
12.50
80
2
260
127-MATTESON-2
Distribution
Unattended
138.00
12.50
120
3
261
77-MAZON
Distribution
Unattended
138.00
34.00
12.50
80
2
262
51-MCCOOK-1
Transmission
Attended
345.00
138.00
34.00
600
2
263
51-MCCOOK-2
Distribution
Attended
138.00
34.00
12.50
180
3
264
51-MCCOOK-3
Distribution
Attended
138.00
12.50
120
3
265
193-MCHENRY-1
Distribution
Unattended
138.00
34.00
12.50
120
2
266
193-MCHENRY-2
Distribution
Unattended
138.00
34.00
106
3
267
139-MENDOTA
Distribution
Unattended
138.00
34.00
12.50
40
1
268
182-MINONK
Distribution
Unattended
138.00
34.00
12.50
40
1
269
451-MOKENA
Distribution
Unattended
138.00
12.50
160
4
270
106-MONTGOMERY-1
Distribution
Unattended
138.00
34.00
12.50
80
2
271
106-MONTGOMERY-2
Distribution
Unattended
138.00
12.50
80
2
272
216-MT PROSPECT
Distribution
Unattended
138.00
12.50
80
2
273
155-NELSON
Transmission
Unattended
345.00
138.00
34.00
900
3
274
406-NEW LENOX
Distribution
Unattended
138.00
12.50
120
3
275
129-NILES-1
Distribution
Unattended
138.00
34.00
12.50
120
2
276
129-NILES-2
Distribution
Unattended
138.00
12.50
120
3
277
565-NORDIC
Distribution
Unattended
138.00
12.50
80
2
278
125-NORMANDY
Distribution
Unattended
138.00
34.00
2.40
60
2
279
525-NORMANTOWN
Distribution
Unattended
138.00
12.50
80
2
280
56-NORTH AURORA-1
Distribution
Unattended
138.00
34.00
12.50
160
4
281
56-NORTH AURORA-2
Distribution
Unattended
138.00
12.50
140
4
282
159-NORTHBROOK
Transmission
Unattended
345.00
138.00
34.00
600
2
283
212-NORTHBROOK
Distribution
Unattended
138.00
12.50
160
4
284
69-NORTH CHICAGO-1
Distribution
Unattended
138.00
34.00
12.50
80
2
285
566-OAKBROOK
Distribution
Unattended
138.00
12.50
160
4
286
505-OAKPARK
Distribution
Unattended
138.00
12.50
120
3
287
204-OLD ELM
Distribution
Unattended
138.00
12.50
120
3
288
470-ORLAND
Distribution
Unattended
138.00
12.50
80
2
289
592-OSWEGO
Distribution
Unattended
138.00
12.50
120
3
290
102-PALATINE-1
Distribution
Unattended
138.00
34.00
12.50
80
2
291
102-PALATINE-2
Distribution
Unattended
138.00
12.50
160
4
292
440-PALOS
Distribution
Unattended
138.00
12.50
80
2
293
457-PARK FOREST
Distribution
Unattended
138.00
12.50
67
2
294
386-PECATONICA
Distribution
Unattended
138.00
12.50
10
1
295
162-PIERPONT-1
Distribution
Unattended
138.00
12.50
60
2
296
162-PIERPONT-2
Distribution
Unattended
69.00
12.50
25
1
297
221-NORTH HUNTLEY
Distribution
Unattended
138.00
12.50
80
2
298
454-PLAINFIELD
Distribution
Unattended
138.00
12.50
120
3
299
444-MINOOKA
Distribution
Unattended
138.00
12.50
80
2
300
167-PLANO-1
Transmission
Unattended
765.00
345.00
34.00
2000
6
301
167-PLANO-2
Transmission
Unattended
345.00
138.00
34.00
300
1
302
527-PLANO
Distribution
Unattended
138.00
34.00
60
1
303
595-PLEASANT HILL
Distribution
Unattended
138.00
12.50
160
4
304
141-PLEASANT VALLEY
Transmission
Unattended
345.00
138.00
34.00
300
1
305
80-PONTIAC MIDPOINT-1
Transmission
Unattended
345.00
138.00
34.00
450
2
306
80-PONTIAC MIDPOINT-2
Distribution
Unattended
138.00
34.00
12.50
180
3
307
235-POPLAR CREEK
Distribution
Unattended
138.00
12.50
80
2
308
117-PROSPECT HEIGHTS-1
Transmission
Unattended
345.00
138.00
34.00
600
2
309
117-PROSPECT HEIGHTS-2
Distribution
Unattended
138.00
12.50
120
3
310
217-PROSPECT HTS
Distribution
Unattended
138.00
12.50
80
2
311
192-RIDGELAND
Distribution
Unattended
138.00
69.00
12.50
600
6
312
414-ROBERTS ROAD
Distribution
Unattended
138.00
12.50
80
2
313
439-ROCKDALE
Distribution
Unattended
138.00
12.50
80
2
314
133-ROCK FALLS-1
Distribution
Unattended
138.00
34.00
12.50
80
2
315
206-ROLLING MEADOWS
Distribution
Unattended
138.00
12.50
160
4
316
411-ROMEOVILLE
Distribution
Unattended
138.00
12.50
80
2
317
163-ROSCOE BERT-1
Distribution
Unattended
138.00
69.00
12.50
50
1
318
163-ROSCOE BERT-2
Distribution
Unattended
138.00
12.50
120
3
319
42-ROUND LAKE-1
Distribution
Unattended
138.00
34.00
12.50
120
2
320
42-ROUND LAKE-2
Distribution
Unattended
138.00
12.50
80
2
321
251-ROUND LAKE BEACH
Distribution
Unattended
138.00
12.50
80
2
322
194-SABROOKE-1
Distribution
Attended
138.00
69.00
12.50
150
2
323
194-SABROOKE-2
Distribution
Attended
138.00
12.50
80
2
324
164-SAND PARK
Distribution
Unattended
138.00
12.50
80
2
325
447-SANDRIDGE
Distribution
Unattended
138.00
12.50
40
2
326
146-SANDWICH
Distribution
Unattended
138.00
34.00
12.50
80
2
327
517-SAYRE
Distribution
Unattended
138.00
12.50
80
2
328
220-SOUTH SCHAUMBURG
Distribution
Unattended
138.00
12.50
120
3
329
253-SCHAUMBURG
Distribution
Unattended
138.00
12.50
160
4
330
431-SHOREWOOD
Distribution
Unattended
138.00
12.50
160
4
331
138-SILVER LAKE
Transmission
Unattended
345.00
138.00
34.00
600
2
332
85-SKOKIE-1
Distribution
Unattended
138.00
34.00
12.50
120
3
333
85-SKOKIE-2
Distribution
Unattended
138.00
12.50
140
4
334
88-SKOKIE-1
Transmission
Unattended
345.00
138.00
34.00
1200
4
335
88-SKOKIE-2
Distribution
Unattended
138.00
34.00
12.50
120
3
336
88-SKOKIE-3
Distribution
Unattended
138.00
12.50
106
3
337
577-SOUTH ELGIN-1
Distribution
Unattended
138.00
12.50
80
2
338
465-SOUTH HOLLAND
Distribution
Unattended
138.00
12.50
120
3
339
577-SOUTH ELGIN-2
Distribution
Unattended
138.00
34.00
120
2
340
390-SOUTH PECATONICA
Distribution
Unattended
138.00
12.50
10
1
341
79-SPAULDING-1
Distribution
Unattended
138.00
34.00
12.50
140
3
342
79-SPAULDING-2
Distribution
Unattended
138.00
12.50
80
2
343
372-STERLING
Distribution
Unattended
138.00
12.50
60
2
344
176-STILLMAN VALLEY
Distribution
Unattended
138.00
34.00
12.50
80
2
345
61-STREATOR
Distribution
Unattended
138.00
34.00
12.50
80
2
346
569-SUGAR GROVE-2
Distribution
Unattended
138.00
34.00
12.50
60
1
347
419-TINLEY PARK
Distribution
Unattended
138.00
12.50
160
4
348
185-TOLLWAY
Transmission
Unattended
345.00
138.00
34.00
300
1
349
207-TONNE-1
Distribution
Unattended
138.00
12.50
160
4
350
207-TONNE-2
Distribution
Unattended
138.00
34.00
12.50
120
2
351
539-WARRENVILLE
Distribution
Unattended
138.00
12.50
120
3
352
113-WATERMAN
Distribution
Unattended
138.00
34.00
4.00
40
1
353
16-WAUKEGAN-1
Transmission
Unattended
345.00
138.00
34.00
600
2
354
16-WAUKEGAN-2
Distribution
Attended
138.00
34.00
12.50
160
4
355
16-WAUKEGAN-3
Distribution
Attended
138.00
12.50
40
2
356
144-WAYNE
Transmission
Unattended
345.00
138.00
34.00
600
2
357
499-WEBER
Distribution
Unattended
138.00
12.50
80
2
358
171-WEMPLETOWN
Transmission
Unattended
345.00
138.00
34.00
300
1
359
131-WEST CHICAGO-1
Distribution
Unattended
138.00
34.00
12.50
160
4
360
131-WEST CHICAGO-2
Distribution
Unattended
138.00
12.50
120
3
361
375-WEST DEKALB
Distribution
Unattended
138.00
12.50
80
2
362
205-WHEELING
Distribution
Unattended
138.00
12.50
80
2
363
18-WILL COUNTY
Distribution
Attended
138.00
34.00
12.50
120
2
364
593-WILLOW SPRINGS
Distribution
Unattended
138.00
12.50
80
2
365
149-WILMINGTON-1
Distribution
Unattended
138.00
34.00
12.00
120
3
366
480-VETERANS
Distribution
Unattended
138.00
12.50
80
2
367
149-WILMINGTON-2
Distribution
Unattended
138.00
12.50
40
1
368
228-WILSON ROAD
Distribution
Unattended
138.00
12.50
120
3
369
112-WILTON CENTER
Transmission
Unattended
765.00
345.00
34.00
2000
6
370
143-WOLFS CROSSING
Transmission
Unattended
345.00
138.00
34.00
300
1
371
453-WOODHILL
Distribution
Unattended
138.00
12.50
113
3
372
559-WOODRIDGE
Distribution
Unattended
138.00
12.50
80
2
373
151-WOODSTOCK
Distribution
Unattended
138.00
12.50
120
3
374
145-YORK CENTER
Distribution
Unattended
138.00
12.50
240
6
375
282 ZION
Distribution
Unattended
138.00
12.50
40
2
376
184-ELK GROVE
Distribution
Unattended
138.00
34.00
120
2
377
GENERAL WAREHOUSE
378
TECHNICAL CENTER
379
E28-ALGONQUIN
Distribution
Unattended
34.00
12.50
28
3
380
513-AURORA-1
Distribution
Unattended
34.00
12.50
31
4
381
513-AURORA-2
Distribution
Unattended
34.00
4.00
13
2
382
W16-AURORA (INDIAN TRAIL)
Distribution
Unattended
34.00
12.50
16
2
383
W73-BALD MOUND
Distribution
Unattended
34.00
12.50
18
2
384
115-BEDFORD PARK
Distribution
Unattended
34.00
12.50
16
2
385
64-BELLWOOD
Distribution
Unattended
34.00
4.00
11
2
386
B20-BELVIDERE
Distribution
Unattended
34.00
12.50
28
3
387
556-BERWYN-2
Distribution
Unattended
12.50
4.00
16
2
388
W26-BIG TIMBER
Distribution
Unattended
34.00
12.50
28
3
389
W16-BLACKBERRY TWP
Distribution
Unattended
34.00
12.50
16
2
390
J69-BRAIDWOOD
Distribution
Unattended
34.00
12.50
25
3
391
W119-BRISTOL TWP
Distribution
Unattended
34.00
12.50
16
2
392
E24-CARY
Distribution
Unattended
34.00
12.50
19
2
393
K19-CEMETARY RD
Distribution
Unattended
34.00
12.50
22
3
394
B31-CHEMUNG
Distribution
Unattended
34.00
12.50
12
2
395
F96-CHICAGO HEIGHTS
Distribution
Unattended
34.00
12.50
12
2
396
59-CICERO-2
Distribution
Unattended
12.50
4.00
20
2
397
S37-BRUCE TWP
Distribution
Unattended
34.00
12.50
12
2
398
W384-BUTTERFIELD-1
Distribution
Unattended
34.00
12.50
10
1
399
B29-BYRON
Distribution
Unattended
34.00
12.50
25
3
400
J68-COAL CITY
Distribution
Unattended
34.00
12.50
19
2
401
F45-CRETE
Distribution
Unattended
34.00
12.50
19
2
402
E77-CRYSTAL LAKE
Distribution
Unattended
34.00
12.50
28
3
403
W50-DEERPATH
Distribution
Unattended
34.00
12.50
25
3
404
H78-DIXON
Distribution
Unattended
34.00
12.50
12
2
405
E71-DORR TWP-1
Distribution
Unattended
34.00
12.50
16
2
406
W38-DOWNERS GROVE TW
Distribution
Unattended
34.00
12.50
19
2
407
A94-DRUCE LAKE
Distribution
Unattended
34.00
12.50
16
2
408
462-DWIGHT
Distribution
Unattended
34.00
12.50
18
2
409
J40 - WESTERN AVE
Distribution
Unattended
34.00
12.50
18
2
410
J46-KAVANAUGH
Distribution
Unattended
34.00
12.50
18
2
411
A71-GRASS LAKE
Distribution
Unattended
34.00
12.50
22
3
412
B12-CAPRON
Distribution
Unattended
34.00
12.00
16
2
413
J15-ELWOOD
Distribution
Unattended
34.00
12.50
19
2
414
C20-EVANSTON
Distribution
Unattended
34.00
12.50
16
2
415
B32-GARDEN PRAIRIE
Distribution
Unattended
34.00
12.50
19
2
416
J49-GOUGAR ROAD
Distribution
Unattended
34.00
12.50
18
2
417
C93-HIGHLAND PARK
Distribution
Unattended
34.00
4.00
11
2
418
W48-HINSDALE
Distribution
Unattended
34.00
12.50
18
2
419
J97-JACKSON ST. (JOLIET)
Distribution
Unattended
34.00
4.00
12
2
420
W118-KENDALL TWP
Distribution
Unattended
34.00
12.50
18
2
421
B15-KINGSTON
Distribution
Unattended
34.00
12.50
11
2
422
B52-LEAF RIVER
Distribution
Unattended
34.00
12.50
15
4
423
H52-LELAND
Distribution
Unattended
34.00
12.50
12
2
424
W20-LILY LAKE
Distribution
Unattended
34.00
12.50
19
2
425
J58-MANHATTAN
Distribution
Unattended
34.00
12.50
16
2
426
B90-MAPLE PARK
Distribution
Unattended
34.00
12.50
16
2
427
123-MARGENGO
Distribution
Unattended
34.00
12.50
19
2
428
W35-UDINA
Distribution
Unattended
34.00
12.50
19
2
429
B10-HARVARD
Distribution
Unattended
34.00
12.50
16
2
430
318-HARVARD
Distribution
Unattended
34.00
12.50
19
2
431
460-HARVEY-1
Distribution
Unattended
34.00
12.50
20
2
432
460-HARVEY-2
Distribution
Unattended
34.00
4.00
20
2
433
C3-HIGHLAND PARK-1
Distribution
Unattended
34.00
12.50
18
2
434
D62-HILLSIDE
Distribution
Unattended
34.00
12.50
19
2
435
H47-HINCKLEY
Distribution
Unattended
34.00
12.50
12
2
436
553-HINSDALE
Distribution
Unattended
34.00
12.50
13
2
437
C65-EVANSTON
Distribution
Unattended
34.00
4.00
12
2
438
C66-EVANSTON
Distribution
Unattended
34.00
12.50
18
2
439
A31-FOX LAKE
Distribution
Unattended
34.00
12.50
19
3
440
W10-FOX RIVER HEIGHTS
Distribution
Unattended
34.00
12.50
19
2
441
D13-FORESTVIEW
Distribution
Unattended
34.00
12.50
16
2
442
121-FREEPORT
Distribution
Unattended
34.00
4.00
19
2
443
H23-FULTON
Distribution
Unattended
34.00
12.50
12
2
444
514-GLEN ELLYN
Distribution
Unattended
34.00
4.00
12
2
445
W115-GLENWOOD PARK
Distribution
Unattended
34.00
12.50
19
2
446
A87-GRAYS LAKE
Distribution
Unattended
34.00
12.50
19
2
447
B16-HAMPSHIRE
Distribution
Unattended
34.00
12.50
28
3
448
D351-HODGINS
Distribution
Unattended
34.00
12.50
16
2
449
E18-HONEY LAKE
Distribution
Unattended
34.00
12.50
19
2
450
E35-HUNTLEY
Distribution
Unattended
34.00
12.50
19
2
451
E29-JOHNSBURG
Distribution
Unattended
34.00
12.50
28
2
452
E19-ISLAND LAKE
Distribution
Unattended
34.00
12.50
19
2
453
450-WASHINGTON ST. JOLIET
Distribution
Unattended
34.00
12.50
19
2
454
LAGRANGE
455
280-LAKE BLUFF
Distribution
Unattended
34.00
4.00
13
3
456
C30-LAKE FOREST
Distribution
Unattended
34.00
12.50
19
2
457
E26-LAKE IN THE HILLS
Distribution
Unattended
34.00
12.50
28
3
458
A47-LAKE VILLA
Distribution
Unattended
34.00
12.50
19
2
459
K34-LEHIGH
Distribution
Unattended
34.00
12.50
16
2
460
J92-LEMONT
Distribution
Unattended
34.00
12.50
12
2
461
A12-LIBERTYVILLE
Distribution
Unattended
34.00
12.50
18
2
462
C81-LINCOLNWOOD
Distribution
Unattended
34.00
4.00
12
2
463
F149-LYNWOOD
Distribution
Unattended
34.00
12.50
13
2
464
K20-MANTENO
Distribution
Unattended
34.00
12.50
18
2
465
B51-MARENGO
Distribution
Unattended
34.00
12.50
16
2
466
D53-MAYWOOD
Distribution
Unattended
12.50
4.00
13
2
467
D187-MAYWOOD-1
Distribution
Unattended
34.00
12.50
16
2
468
H39-MENDOTA
Distribution
Unattended
34.00
12.50
25
3
469
E16-MCHENRY
Distribution
Unattended
34.00
12.50
19
2
470
W336-MILTON TWP
Distribution
Unattended
34.00
12.50
19
2
471
K18-MOMENCE
Distribution
Unattended
34.00
12.50
19
2
472
422-MORRIS
Distribution
Unattended
34.00
12.50
18
2
473
H26-MORRISON
Distribution
Unattended
34.00
12.50
12
2
474
B30-MT MORRIS
Distribution
Unattended
34.00
12.50
16
2
475
E8-NERGE
Distribution
Unattended
34.00
12.50
16
2
476
W71-NORTH AURORA
Distribution
Unattended
34.00
12.50
19
2
477
69-NORTH CHICAGO-2
Distribution
Unattended
34.00
12.50
19
2
478
A24-NORTH CHICAGO
Distribution
Unattended
34.00
12.50
19
2
479
D46-NORTHLAKE
Distribution
Unattended
34.00
12.50
19
2
480
D177-O'HARE FIELD
Distribution
Unattended
34.00
12.50
13
2
481
D179-O'HARE FIELD
Distribution
Unattended
34.00
12.50
19
3
482
D180-O'HARE FIELD
Distribution
Unattended
34.00
12.50
22
3
483
505-OAK PARK
Distribution
Unattended
12.50
4.00
18
3
484
S43-ODELL
Distribution
Unattended
34.00
12.50
16
2
485
W18-ORCHARD RD
Distribution
Unattended
34.00
12.50
16
2
486
B53-OREGON
Distribution
Unattended
34.00
12.50
18
2
487
E12-PALATINE
Distribution
Unattended
34.00
12.50
19
2
488
C55-PARK RIDGE
Distribution
Unattended
34.00
4.00
13
2
489
F17-PEOTONE
Distribution
Unattended
34.00
12.50
19
2
490
W25-PINGREE GROVE
Distribution
Unattended
34.00
12.50
16
2
491
J31-PLAINFIELD
Distribution
Unattended
34.00
12.50
19
2
492
H65-PLANO
Distribution
Unattended
34.00
12.50
17
2
493
W211-PLATO CENTER
Distribution
Unattended
34.00
12.50
16
2
494
B36-POLO
Distribution
Unattended
34.00
12.50
16
2
495
S66-PONTIAC-1
Distribution
Unattended
34.00
12.50
16
2
496
471-PONTIAC
Distribution
Unattended
34.00
12.50
19
2
497
B11-POPLAR GROVE
Distribution
Unattended
34.00
12.50
19
2
498
W51-RANDALL ROAD
Distribution
Unattended
34.00
12.50
25
3
499
E82-RICHMOND
Distribution
Unattended
34.00
12.50
19
2
500
J28-RIDGE ROAD
Distribution
Unattended
34.00
12.50
18
2
501
B55-ROCK CITY
Distribution
Unattended
34.00
12.50
13
2
502
E69-ROLLING MEADOWS
Distribution
Unattended
34.00
12.50
28
3
503
A67-RONDOUT
Distribution
Unattended
34.00
12.50
25
3
504
W236-ROSELLE
Distribution
Unattended
34.00
12.50
19
2
505
H60-SANDWICH
Distribution
Unattended
34.00
12.50
16
2
506
H14-SANDWICH
Distribution
Unattended
34.00
12.50
28
3
507
F12-SAUK TRAIL
Distribution
Unattended
34.00
12.50
19
2
508
D63-SCHILLER PARK
Distribution
Unattended
34.00
12.50
25
3
509
C77-SKOKIE
Distribution
Unattended
34.00
4.00
13
2
510
85-SKOKIE
Distribution
Unattended
34.00
4.00
11
2
511
88-SKOKIE
Distribution
Unattended
34.00
4.00
13
2
512
H53-SOMONAUK
Distribution
Unattended
34.00
12.50
19
2
513
E79-SOUTH WONDERLAKE
Distribution
Unattended
34.00
12.50
16
2
514
E20-SPRING GROVE
Distribution
Unattended
34.00
12.50
28
3
515
H25-STERLING
Distribution
Unattended
34.00
12.50
16
2
516
S61-STREATOR
Distribution
Unattended
34.00
4.00
13
2
517
S44-STREATOR
Distribution
Unattended
34.00
12.50
16
2
518
H70-SUBLETTE
Distribution
Unattended
34.00
12.50
14
2
519
D40-SUMMIT
Distribution
Unattended
34.00
12.50
16
2
520
316-SYCAMORE
Distribution
Unattended
34.00
12.50
44
5
521
J17-TROY TWP
Distribution
Unattended
34.00
12.50
19
2
522
459-VOLLMER ROAD-1
Distribution
Unattended
34.00
12.50
25
4
523
W39-WASCO
Distribution
Unattended
34.00
12.50
28
3
524
E11-WAUCONDA
Distribution
Unattended
34.00
12.50
25
3
525
E22-WAUCONDA
Distribution
Unattended
34.00
12.50
25
3
526
A41-WAUKEGAN-2
Distribution
Unattended
34.00
4.00
13
2
527
A68-WAUKEGAN
Distribution
Unattended
34.00
12.50
16
2
528
A70-WAUKEGAN
Distribution
Unattended
34.00
12.50
25
3
529
W33-WAYNE
Distribution
Unattended
34.00
12.50
19
2
530
558-WESTMONT-1
Distribution
Unattended
34.00
12.50
31
4
531
W30-WHEATON
Distribution
Unattended
34.00
12.50
19
2
532
249-WILMETTE-1
Distribution
Unattended
34.00
12.50
34
4
533
249-WILMETTE-2
Distribution
Unattended
34.00
4.00
16
2
534
B95-SOUTH DEKALB
Distribution
Unattended
34.00
12.50
18
2
535
W29-WINFIELD TWP
Distribution
Unattended
34.00
12.50
13
2
536
E17-WONDER LAKE
Distribution
Unattended
34.00
12.50
16
2
537
G78-WORTH
Distribution
Unattended
34.00
12.50
16
2
538
A82-ZION
Distribution
Unattended
34.00
12.50
13
2
539
C23-SEARLE
Distribution
Unattended
34.00
12.50
19
2
540
A91-ZION
Distribution
Unattended
34.00
12.50
16
2
541
J25- JACKSON TWP.
Distribution
Unattended
34.00
12.50
18
2
542
W148-AURORA TWP
Distribution
Unattended
34.00
12.50
16
2
543
TOTAL OUTSIDE CHICAGO (OVER 10MVA)
49,461.00
11,685.20
1,883.40
53811
1042
544
OUTSIDE CHICAGO (UNDER 10MVA)
545
W348-BENSENVILLE-1
Distribution
Unattended
34.00
12.50
9
1
546
W348-BENSENVILLE-2
Distribution
Unattended
34.00
4.00
3
1
547
D69-BROADVIEW-1
Distribution
Unattended
34.00
12.50
6
1
548
D69-BROADVIEW-2
Distribution
Unattended
34.00
4.00
5
1
549
W218-CARPENTERSVILLE-1
Distribution
Unattended
34.00
12.50
9
1
550
W218-CARPENTERSVILLE-2
Distribution
Unattended
34.00
4.00
5
1
551
E71-DORR TWP-2
Distribution
Unattended
34.00
4.00
3
1
552
B45-LENA
Distribution
Unattended
34.00
12.50
6
1
553
J16-EASTERN AVE (JOLIET)-1
Distribution
Unattended
34.00
12.50
6
1
554
J16-EASTERN AVE (JOLIET)-2
Distribution
Unattended
34.00
4.00
6
1
555
501-ELMHURST-1
Distribution
Unattended
34.00
12.50
6
1
556
501-ELMHURST-2
Distribution
Unattended
34.00
4.00
8
2
557
W345-ELMHURST-1
Distribution
Unattended
34.00
12.50
9
1
558
W345-ELMHURST-2
Distribution
Unattended
34.00
4.00
6
1
559
C53-EVANSTON-1
Distribution
Unattended
34.00
12.50
9
1
560
C53-EVANSTON-2
Distribution
Unattended
34.00
4.00
6
1
561
D99-FRANKLIN PARK-1
Distribution
Unattended
34.00
12.50
6
1
562
D99-FRANKLIN PARK-2
Distribution
Unattended
34.00
4.00
6
1
563
B17-GENOA-1
Distribution
Unattended
34.00
12.50
9
1
564
B17-GENOA-2
Distribution
Unattended
34.00
4.00
3
1
565
C62-GLENCOE-1
Distribution
Unattended
34.00
4.00
5
1
566
C62-GLENCOE-2
Distribution
Unattended
12.50
4.00
6
1
567
C3-HIGHLAND PARK-2
Distribution
Unattended
34.00
4.00
3
1
568
G88-HOMETOWN-1
Distribution
Unattended
34.00
12.50
6
1
569
G88-HOMETOWN-2
Distribution
Unattended
34.00
4.00
6
1
570
D16-LAGRANGE HIGHLANDS-1
Distribution
Unattended
34.00
12.50
9
1
571
D16-LAGRANGE HIGHLANDS-2
Distribution
Unattended
34.00
4.00
6
1
572
D87-LEYDEN TWP-1
Distribution
Unattended
34.00
12.50
9
1
573
D87-LEYDEN TWP-2
Distribution
Unattended
34.00
4.00
6
1
574
D 229-LYONS TWP-1
Distribution
Unattended
34.00
12.50
6
1
575
D 229-LYONS TWP-2
Distribution
Unattended
34.00
4.00
6
1
576
D187-MAYWOOD-2
Distribution
Unattended
34.00
4.00
6
1
577
D20-MELROSE PARK-1
Distribution
Unattended
34.00
12.50
9
1
578
D20-MELROSE PARK-2
Distribution
Unattended
34.00
4.00
9
1
579
311-MENDOTA-1
Distribution
Unattended
34.00
12.50
6
1
580
311-MENDOTA-2
Distribution
Unattended
34.00
4.00
9
2
581
C33-NILES-1
Distribution
Unattended
34.00
12.50
6
1
582
C33-NILES-2
Distribution
Unattended
34.00
4.00
6
1
583
C19-PARK RIDGE-1
Distribution
Unattended
34.00
4.00
5
3
584
C19-PARK RIDGE-2
Distribution
Unattended
34.00
12.50
9
1
585
S66-PONTIAC-2
Distribution
Unattended
34.00
4.00
8
2
586
D133-RIVER GROVE-1
Distribution
Unattended
34.00
12.50
9
1
587
D133-RIVER GROVE-2
Distribution
Unattended
34.00
4.00
5
1
588
D175-SCHILLER PARK-1
Distribution
Unattended
34.00
4.00
6
1
589
D175-SCHILLER PARK-2
Distribution
Unattended
34.00
12.50
9
1
590
79-SPAULDING
Distribution
Unattended
34.00
12.50
9
1
591
H62-STERLING-1
Distribution
Unattended
34.00
12.50
6
1
592
H62-STERLING-2
Distribution
Unattended
34.00
4.00
5
1
593
C73-TECHNY-1
Distribution
Unattended
34.00
12.50
9
1
594
C73-TECHNY-2
Distribution
Unattended
34.00
4.00
3
1
595
C96-TECHNY SOUTH
Distribution
Unattended
34.00
12.50
9
1
596
W334-VILLA PARK-1
Distribution
Unattended
34.00
12.50
6
1
597
W334-VILLA PARK-2
Distribution
Unattended
34.00
4.00
6
1
598
459-VOLLMER ROAD-2
Distribution
Unattended
34.00
4.00
3
1
599
A41-WAUKEGAN-1
Distribution
Unattended
34.00
12.50
6
1
600
A43-WAUKEGAN-1
Distribution
Unattended
34.00
12.50
6
1
601
A43-WAUKEGAN-2
Distribution
Unattended
34.00
4.00
9
1
602
B49-KENT
Distribution
Unattended
34.00
12.50
9
1
603
G42-WORTH-1
Distribution
Unattended
34.00
12.50
9
1
604
G42-WORTH-2
Distribution
Unattended
34.00
4.00
3
1
605
558-WESTMONT-2
Distribution
Unattended
34.00
4.00
6
1
606
R19-ACORN
Distribution
Unattended
12.50
4.00
5
1
607
W346-ADDISON TWP
Distribution
Unattended
34.00
12.50
6
1
608
B89-AFTON
Distribution
Unattended
34.00
12.50
5
1
609
H67-AMBOY
Distribution
Unattended
34.00
12.50
6
1
610
H43-AMBOY (GREEN RIVER)
Distribution
Unattended
34.00
12.50
6
1
611
E27-ARLINGTON HEIGHTS
Distribution
Unattended
34.00
4.00
3
1
612
E39-ARLINGTON HEIGHTS
Distribution
Unattended
34.00
4.00
3
1
613
E70-ARLINGTON HEIGHTS
Distribution
Unattended
34.00
4.00
5
1
614
E81-ARLINGTON HEIGHTS
Distribution
Unattended
34.00
4.00
6
1
615
K32-AROMA PARK
Distribution
Unattended
34.00
12.50
6
1
616
H49-ASHTON
Distribution
Unattended
34.00
12.50
6
1
617
W114-AURORA (ILLINOIS AVE)
Distribution
Unattended
34.00
4.00
3
1
618
W152-AURORA (KENSINGTON)
Distribution
Unattended
34.00
12.50
6
1
619
J21-AUX SABLE TWP
Distribution
Unattended
34.00
12.50
9
1
620
B39-BAILEYVILLE
Distribution
Unattended
34.00
12.50
9
1
621
W233-BARTLETT
Distribution
Unattended
34.00
12.50
9
1
622
A57-BEACH
Distribution
Unattended
34.00
12.50
6
1
623
R23-BEATTIE
Distribution
Unattended
12.50
4.00
5
1
624
F16-BEECHER
Distribution
Unattended
34.00
12.50
9
1
625
J81-BELLE AV
Distribution
Unattended
34.00
4.00
3
1
626
D12-BELLWOOD
Distribution
Unattended
34.00
4.00
6
1
627
B19-BELVIDERE-1
Distribution
Unattended
34.00
4.00
5
1
628
W349-BENSENVILLE
Distribution
Unattended
34.00
4.00
6
2
629
D86-BERKELEY
Distribution
Unattended
34.00
4.00
6
1
630
D34-BERWYN
Distribution
Unattended
12.50
4.00
6
1
631
S26-BLACKSTONE
Distribution
Unattended
34.00
12.50
3
1
632
J53-BLODGETT RD
Distribution
Unattended
34.00
12.50
9
1
633
F122-BLOOM TWP-1
Distribution
Unattended
34.00
12.50
9
1
634
F122-BLOOM TWP-2
Distribution
Unattended
34.00
4.00
3
1
635
F79-BLOOM TWP
Distribution
Unattended
34.00
4.00
9
1
636
G16-BLUE ISLAND
Distribution
Unattended
34.00
4.00
8
1
637
G64-BLUE ISLAND
Distribution
Unattended
34.00
4.00
3
1
638
G81-BLUE ISLAND
Distribution
Unattended
34.00
4.00
3
1
639
B19-BELVIDERE-2
Distribution
Unattended
34.00
12.50
9
1
640
J88-BLUFF ST (JOLIET)
Distribution
Unattended
34.00
4.00
5
1
641
K40-BOURBONNAIS TWP
Distribution
Unattended
34.00
12.50
9
1
642
K29-BRADLEY
Distribution
Unattended
34.00
4.00
5
1
643
C34-BRAESIDE
Distribution
Unattended
34.00
12.50
6
1
644
D242-BRIDGEVIEW
Distribution
Unattended
34.00
12.50
6
1
645
D47-BROADVIEW-1
Distribution
Unattended
34.00
12.50
6
1
646
D47-BROADVIEW-2
Distribution
Unattended
34.00
4.00
3
1
647
D80-BROADVIEW
Distribution
Unattended
34.00
12.50
9
1
648
J55-BROADWAY ST
Distribution
Unattended
34.00
4.00
3
1
649
D115-BROOKFIELD
Distribution
Unattended
34.00
4.00
6
1
650
D140-BROOKFIELD
Distribution
Unattended
34.00
4.00
6
1
651
E46-BURTON BRIDGE
Distribution
Unattended
34.00
12.50
9
1
652
G30-CALUMET CITY
Distribution
Unattended
34.00
4.00
3
1
653
G100-CALUMET CITY
Distribution
Unattended
34.00
4.00
5
1
654
B47-CEDARVILLE
Distribution
Unattended
34.00
12.50
6
1
655
D11-CENTERPOINT
Distribution
Unattended
34.00
12.50
9
1
656
J67-CHANNAHON
Distribution
Unattended
34.00
12.50
3
1
657
B50-CHERRY GROVE
Distribution
Unattended
34.00
12.50
8
1
658
J84-CHERRY ST (JOLIET)
Distribution
Unattended
34.00
4.00
5
1
659
F91-CHICAGO HEIGHTS
Distribution
Unattended
34.00
4.00
3
1
660
F73-CHICAGO HEIGHTS
Distribution
Unattended
34.00
12.50
6
1
661
D15-CICERO
Distribution
Unattended
12.50
4.00
7
1
662
D100-CICERO
Distribution
Unattended
12.50
4.00
6
1
663
D151-CICERO
Distribution
Unattended
12.50
4.00
6
1
664
D217-CICERO
Distribution
Unattended
12.50
4.00
5
1
665
B86-CLARE
Distribution
Unattended
34.00
12.50
6
1
666
B35-COLETA
Distribution
Unattended
34.00
12.50
5
1
667
S42-CORNELL
Distribution
Unattended
34.00
12.50
3
1
668
D44-COUNTRYSIDE
Distribution
Unattended
34.00
12.50
9
1
669
B26-DAVIS JUNCTION
Distribution
Unattended
34.00
12.50
9
1
670
H51-INDIAN CREEK
Distribution
Unattended
34.00
12.50
9
1
671
J48-BRANDON ROAD
Distribution
Unattended
34.00
13.00
9
1
672
C51-DESPLAINES
Distribution
Unattended
34.00
4.00
6
1
673
C79-DESPLAINES
Distribution
Unattended
34.00
4.00
6
1
674
G33-DOLTON
Distribution
Unattended
34.00
4.00
675
G126-DOLTON
Distribution
Unattended
34.00
4.00
6
1
676
W41-DOWNERS GROVE
Distribution
Unattended
34.00
12.50
9
1
677
G909-DOLTON-1
Distribution
Unattended
34.00
12.50
9
1
678
G909-DOLTON-2
Distribution
Unattended
34.00
12.50
9
1
679
W384-BUTTERFIELD-2
Distribution
Unattended
34.00
12.50
9
1
680
W43-DOWNERS GROVE
Distribution
Unattended
34.00
4.00
6
1
681
J76-DUPONT RD
Distribution
Unattended
34.00
12.50
9
1
682
H50-EARLVILLE
Distribution
Unattended
34.00
12.50
6
1
683
K42-EAST KANKAKEE
Distribution
Unattended
34.00
12.50
6
1
684
B54-EAST OREGON
Distribution
Unattended
34.00
12.50
6
1
685
S48-EAST STREATOR
Distribution
Unattended
34.00
12.50
9
1
686
R26-EIGHTEENTH AVE
Distribution
Unattended
12.50
4.00
5
1
687
W13-ELDAMAIN
Distribution
Unattended
34.00
12.50
9
1
688
W202-ELGIN
Distribution
Unattended
34.00
12.50
9
1
689
W209-ELGIN
Distribution
Unattended
34.00
4.00
5
1
690
W342-ELMHURST
Distribution
Unattended
34.00
4.00
6
1
691
W343-ELMHURST-1
Distribution
Unattended
34.00
12.50
6
1
692
W343-ELMHURST-2
Distribution
Unattended
34.00
4.00
3
1
693
D111-ELMWOOD PARK
Distribution
Unattended
12.50
4.00
6
1
694
D149-ELMWOOD PARK
Distribution
Unattended
12.50
4.00
6
1
695
D173-ELMWOOD PARK
Distribution
Unattended
12.50
4.00
7
1
696
S41-EPPARDS POINT
Distribution
Unattended
34.00
12.50
4
1
697
C41-EVANSTON
Distribution
Unattended
34.00
4.00
9
1
698
C43-EVANSTON
Distribution
Unattended
34.00
4.00
6
1
699
C54-EVANSTON
Distribution
Unattended
34.00
12.50
9
1
700
C75-EVANSTON
Distribution
Unattended
34.00
4.00
6
1
701
C83-EVANSTON
Distribution
Unattended
34.00
12.50
9
1
702
G69-EVERGREEN PARK
Distribution
Unattended
34.00
4.00
6
1
703
G82-EVERGREEN PARK
Distribution
Unattended
34.00
4.00
6
1
704
K39-EXLINE ROAD
Distribution
Unattended
34.00
12.50
6
1
705
W102-FABYAN
Distribution
Unattended
34.00
12.50
6
1
706
D255-FORESTVIEW
Distribution
Unattended
34.00
12.50
9
1
707
B37-FORRESTON
Distribution
Unattended
34.00
12.50
5
1
708
R35-FOURTEENTH ST.
Distribution
Unattended
12.50
4.00
5
1
709
R24-FOURTH AVE.
Distribution
Unattended
34.00
4.00
5
1
710
E72-FOX RIVER GROVE
Distribution
Unattended
34.00
4.00
9
1
711
B64-FRANKLIN GROVE
Distribution
Unattended
34.00
12.50
6
1
712
B56-FREEPORT
Distribution
Unattended
34.00
4.00
3
1
713
A50-GAGES LAKE
Distribution
Unattended
34.00
12.50
6
1
714
H27-GALT
Distribution
Unattended
34.00
12.50
6
1
715
132-GARDEN PLAIN-2
Distribution
Unattended
34.00
12.50
6
1
716
S63-GARDNER
Distribution
Unattended
34.00
12.50
9
1
717
C61-GARNETT
Distribution
Unattended
34.00
12.50
9
1
718
W330-GLEN ELLYN
Distribution
Unattended
34.00
4.00
3
1
719
C92-GLENCOE
Distribution
Unattended
34.00
4.00
5
1
720
C7-GLENVIEW
Distribution
Unattended
34.00
4.00
5
1
721
C25-GLENVIEW
Distribution
Unattended
34.00
12.50
9
1
722
C80-GLENVIEW
Distribution
Unattended
34.00
12.50
9
1
723
C95-GLENVIEW
Distribution
Unattended
34.00
4.00
6
1
724
F36-GOODENOW
Distribution
Unattended
34.00
12.50
9
1
725
J66-GOOSE LAKE
Distribution
Unattended
34.00
12.50
6
1
726
S25-GRAND RAPIDS
Distribution
Unattended
34.00
12.50
6
1
727
S29-GRAND RIDGE
Distribution
Unattended
34.00
12.50
6
1
728
K44-GRANT PARK
Distribution
Unattended
34.00
12.50
6
1
729
A81-GREAT LAKES
Distribution
Unattended
34.00
12.50
6
1
730
E59-HAEGER'S CORNER
Distribution
Unattended
34.00
12.50
9
1
731
E21-HARTLAND
Distribution
Unattended
34.00
12.50
6
1
732
B14-HARVARD
Distribution
Unattended
34.00
4.00
3
1
733
G83-HARVEY
Distribution
Unattended
34.00
4.00
3
1
734
G113-HARVEY
Distribution
Unattended
34.00
4.00
6
1
735
B23-HERBERT
Distribution
Unattended
34.00
4.00
1
1
736
C82-HIGHLAND PARK
Distribution
Unattended
34.00
4.00
5
1
737
J62-HOMER TWP
Distribution
Unattended
34.00
12.50
9
1
738
F24-HOMEWOOD
Distribution
Unattended
34.00
4.00
6
2
739
F75-HOMEWOOD
Distribution
Unattended
34.00
4.00
3
1
740
H38-HOOPHOLE
Distribution
Unattended
34.00
12.50
4
1
741
J32-KAHLER RD
Distribution
Unattended
34.00
12.50
6
1
742
K23-KANKAKEE
Distribution
Unattended
34.00
4.00
4
1
743
K33-KANKAKEE
Distribution
Unattended
34.00
12.50
6
1
744
S14-KERNAN
Distribution
Unattended
34.00
12.50
1
1
745
B40-KETCHUM
Distribution
Unattended
34.00
12.50
9
1
746
B28-KIRKLAND
Distribution
Unattended
34.00
12.50
6
2
747
D172-LAGRANGE
Distribution
Unattended
34.00
4.00
6
1
748
D125-LAGRANGE PARK
Distribution
Unattended
34.00
4.00
6
1
749
C76-LAKE FOREST
Distribution
Unattended
34.00
4.00
6
2
750
B63-LANARK
Distribution
Unattended
34.00
12.50
9
1
751
H57-LEE
Distribution
Unattended
34.00
12.50
3
1
752
J87-LEMONT
Distribution
Unattended
34.00
12.50
9
1
753
D45-LEYDEN TWP
Distribution
Unattended
34.00
4.00
6
1
754
D67-LEYDEN TWP
Distribution
Unattended
34.00
12.50
6
1
755
D267-LEYDEN TWP
Distribution
Unattended
34.00
4.00
6
1
756
A64-LIBERTYVILLE
Distribution
Unattended
34.00
4.00
3
1
757
C22-LINCOLNWOOD
Distribution
Unattended
34.00
4.00
9
2
758
J24-LISBON
Distribution
Unattended
34.00
12.50
6
1
759
W44-LISLE
Distribution
Unattended
34.00
12.50
6
1
760
J18-LOCKPORT
Distribution
Unattended
34.00
12.50
9
1
761
S40-LODEMIA
Distribution
Unattended
34.00
12.50
3
1
762
120-LOMBARD
Distribution
Unattended
34.00
12.50
3
1
763
W52-LOMBARD
Distribution
Unattended
34.00
4.00
5
3
764
W331-LOMBARD
Distribution
Unattended
34.00
4.00
3
1
765
J54-LORENZO
Distribution
Unattended
34.00
4.00
766
S21-LOSTANT
Distribution
Unattended
34.00
12.50
6
1
767
S27-LOWELL
Distribution
Unattended
34.00
12.50
3
1
768
H28-LYNDON
Distribution
Unattended
34.00
12.50
6
1
769
D89-LYONS
Distribution
Unattended
34.00
4.00
5
1
770
S35-MANVILLE
Distribution
Unattended
34.00
12.50
3
1
771
G128-MARKHAM-1
Distribution
Unattended
34.00
12.50
6
1
772
G128-MARKHAM-2
Distribution
Unattended
34.00
4.00
3
1
773
D216-MAYWOOD
Distribution
Unattended
34.00
4.00
6
1
774
S67-MAZON
Distribution
Unattended
34.00
12.50
3
1
775
W216-MEADOWDALE
Distribution
Unattended
34.00
12.50
9
1
776
D201-MELROSE PARK
Distribution
Unattended
34.00
4.00
6
1
777
J38-MESSENGER WOODS
Distribution
Unattended
34.00
12.50
778
B46-MILLEDGEVILLE
Distribution
Unattended
34.00
12.50
6
1
779
W31-MILTON TWP-1
Distribution
Unattended
34.00
12.50
6
1
780
W31-MILTON TWP-2
Distribution
Unattended
34.00
4.00
3
1
781
S39-MINONK
Distribution
Unattended
34.00
12.50
9
1
782
J20-MISSISSIPPI
Distribution
Unattended
34.00
12.50
9
1
783
B25-MONROE CENTER
Distribution
Unattended
34.00
12.00
9
1
784
H29-MORRISON
Distribution
Unattended
34.00
4.00
4
1
785
C6-MORTON GROVE
Distribution
Unattended
34.00
4.00
6
1
786
C52-MORTON GROVE
Distribution
Unattended
34.00
4.00
5
1
787
C78-MORTON GROVE
Distribution
Unattended
34.00
4.00
6
2
788
C26-MT PROSPECT
Distribution
Unattended
34.00
4.00
6
2
789
A35-MUNDELEIN
Distribution
Unattended
34.00
4.00
3
1
790
W46-NAPERVILLE
Distribution
Unattended
34.00
12.50
6
1
791
J60-NEW LENNOX
Distribution
Unattended
34.00
12.50
6
1
792
R14-NORTH
Distribution
Unattended
12.50
4.00
5
1
793
B96-NORTH HAMPSHIRE
Distribution
Unattended
34.00
12.50
9
1
794
C85-NORTHBROOK-1
Distribution
Unattended
34.00
4.00
6
1
795
D51-NORTHLAKE
Distribution
Unattended
34.00
4.00
3
1
796
K50-NORTH MOMENCE
Distribution
Unattended
34.00
12.50
9
1
797
G39-OAK LAWN
Distribution
Unattended
34.00
4.00
5
1
798
G66-OAK LAWN
Distribution
Unattended
34.00
4.00
6
1
799
G125-OAK LAWN
Distribution
Unattended
34.00
4.00
6
1
800
D204-OAK PARK
Distribution
Unattended
12.50
4.00
6
1
801
D292-OAK PARK
Distribution
Unattended
12.50
4.00
6
1
802
H44-OHIO
Distribution
Unattended
34.00
12.50
3
1
803
C21-OPTIMA
Distribution
Unattended
34.00
12.50
9
1
804
G99-PALOS HEIGHTS
Distribution
Unattended
34.00
12.50
6
1
805
F29-PARK FOREST
Distribution
Unattended
34.00
4.00
3
1
806
F41-PARK FOREST
Distribution
Unattended
34.00
4.00
3
1
807
F111-PARK FOREST
Distribution
Unattended
34.00
4.00
5
1
808
C36-PARK RIDGE
Distribution
Unattended
34.00
4.00
6
1
809
C87-PARK RIDGE
Distribution
Unattended
34.00
4.00
3
1
810
C85-NORTHBROOK-2
Distribution
Unattended
34.00
12.50
3
1
811
C97-PARK RIDGE
Distribution
Unattended
34.00
12.50
9
1
812
H59-PAW PAW
Distribution
Unattended
34.00
12.50
3
1
813
B42-PEARL CITY
Distribution
Unattended
34.00
12.50
5
1
814
H66-PLANO
Distribution
Unattended
34.00
12.50
9
1
815
H10-PRARIEVILLE
Distribution
Unattended
34.00
12.50
8
1
816
H91-PROPHETSTOWN
Distribution
Unattended
34.00
12.50
8
1
817
S12-RANSOM
Distribution
Unattended
34.00
12.50
8
1
818
B48-RINK
Distribution
Unattended
34.00
12.50
6
1
819
D143-RIVER FOREST
Distribution
Unattended
12.50
4.00
6
1
820
G31-RIVERDALE
Distribution
Unattended
34.00
4.00
3
1
821
D103-RIVERSIDE
Distribution
Unattended
12.50
4.00
6
1
822
D241-RIVERSIDE
Distribution
Unattended
34.00
4.00
6
1
823
133-ROCK FALLS-2
Distribution
Unattended
34.00
12.50
9
1
824
H41-ROCK FALLS
Distribution
Unattended
34.00
12.50
9
1
825
R18-ROCKTON AVE
Distribution
Unattended
12.50
4.00
5
1
826
A37-ROUND LAKE BEACH
Distribution
Unattended
34.00
12.50
9
1
827
S11-ROWE
Distribution
Unattended
34.00
12.50
2
1
828
S20-RUTLAND
Distribution
Unattended
34.00
12.50
9
1
829
J23-SARATOGA
Distribution
Unattended
34.00
12.50
9
1
830
J65-SENECA
Distribution
Unattended
34.00
12.50
6
1
831
H56-SHABBONA
Distribution
Unattended
34.00
12.50
3
1
832
E38-SILVER LAKE
Distribution
Unattended
34.00
12.50
6
1
833
C28-SKOKIE
Distribution
Unattended
34.00
4.00
6
1
834
C32-SKOKIE
Distribution
Unattended
34.00
4.00
6
1
835
C69-SKOKIE
Distribution
Unattended
34.00
4.00
6
1
836
C74-SKOKIE
Distribution
Unattended
34.00
4.00
6
1
837
C86-SKOKIE
Distribution
Unattended
34.00
4.00
6
1
838
C90-SKOKIE
Distribution
Unattended
34.00
4.00
6
1
839
C94-SKOKIE
Distribution
Unattended
34.00
4.00
6
1
840
H76-SOUTH DIXON
Distribution
Unattended
34.00
12.50
9
1
841
S47-SOUTH WILMINGTON
Distribution
Unattended
34.00
12.50
9
1
842
E10-SOUTH HUNTLEY
Distribution
Unattended
34.00
12.50
9
1
843
K45-ST.ANNE
Distribution
Unattended
34.00
12.50
6
1
844
K52-ST.GEORGE
Distribution
Unattended
34.00
12.50
9
1
845
F132-STEGER
Distribution
Unattended
34.00
4.00
3
1
846
H18-STERLING
Distribution
Unattended
34.00
12.50
5
1
847
312-STEWARD
Distribution
Unattended
34.00
12.50
3
1
848
D114-STICKNEY
Distribution
Unattended
34.00
12.50
6
1
849
D244-STICKNEY TWP
Distribution
Unattended
34.00
12.50
9
1
850
B27-STILLMAN VALLEY
Distribution
Unattended
34.00
12.50
6
1
851
B43-STOCKTON
Distribution
Unattended
34.00
12.50
6
1
852
D194-STONE PARK
Distribution
Unattended
34.00
4.00
6
1
853
R21-SUNSET
Distribution
Unattended
12.50
4.00
5
1
854
W28-SUNSET PARK
Distribution
Unattended
34.00
12.50
6
1
855
F115-THORNTON
Distribution
Unattended
34.00
4.00
3
1
856
G 19 TINLEY PARK
Distribution
Unattended
34.00
12.50
6
1
857
S15-TOLUCA
Distribution
Unattended
34.00
12.50
6
1
858
S19-TONICA
Distribution
Unattended
34.00
12.00
9
1
859
W64-TRI STATE-1
Distribution
Unattended
34.00
12.50
6
1
860
W64-TRI STATE-2
Distribution
Unattended
34.00
4.00
3
1
861
B57-UNION
Distribution
Unattended
34.00
12.50
9
1
862
S36-VERONA
Distribution
Unattended
34.00
12.50
3
1
863
W333-VILLA PARK
Distribution
Unattended
34.00
4.00
6
1
864
A27-WADSWORTH-1
Distribution
Unattended
34.00
12.50
6
1
865
A27-WADSWORTH-2
Distribution
Unattended
34.00
4.00
3
1
866
H40-WALNUT
Distribution
Unattended
34.00
12.50
6
1
867
K15-WARNER BRIDGE
Distribution
Unattended
34.00
12.50
6
1
868
A92-WARREN
Distribution
Unattended
34.00
4.00
1
1
869
B44-WARREN
Distribution
Unattended
34.00
12.50
8
1
870
J33-WASH ST (JOLIET)
Distribution
Unattended
34.00
12.50
9
1
871
H54-WATERMAN
Distribution
Unattended
34.00
12.50
6
1
872
H55-WATERMAN
Distribution
Unattended
34.00
4.00
2
1
873
E41-WAUCONDA
Distribution
Unattended
34.00
4.00
3
1
874
A49-WAUKEGAN
Distribution
Unattended
34.00
4.00
3
1
875
A56-WAUKEGAN
Distribution
Unattended
34.00
4.00
6
1
876
A61-WAUKEGAN-1
Distribution
Unattended
34.00
12.50
6
1
877
A61-WAUKEGAN-2
Distribution
Unattended
34.00
4.00
3
1
878
A63-WAUKEGAN
Distribution
Unattended
34.00
4.00
5
1
879
A65-WAUKEGAN
Distribution
Unattended
34.00
4.00
3
1
880
J13-WAUPONSEE
Distribution
Unattended
34.00
12.50
6
1
881
S16-WENONA-1
Distribution
Unattended
34.00
12.50
3
1
882
S16-WENONA-2
Distribution
Unattended
34.00
4.00
2
1
883
R22-WEST
Distribution
Unattended
12.50
4.00
5
1
884
W335-WEST CHICAGO-1
Distribution
Unattended
34.00
12.50
6
1
885
W335-WEST CHICAGO-2
Distribution
Unattended
34.00
4.00
3
1
886
W17-WEST SUGAR GROVE
Distribution
Unattended
34.00
12.50
9
1
887
D24-WESTERN SPRINGS
Distribution
Unattended
34.00
4.00
9
1
888
W340-WEISBROOK
Distribution
Unattended
34.00
12.50
9
1
889
W304-WHEATON
Distribution
Unattended
34.00
12.50
9
1
890
C31-WILMETTE
Distribution
Unattended
34.00
4.00
5
1
891
C56-WILMETTE
Distribution
Unattended
34.00
4.00
6
1
892
C89-WILMETTE
Distribution
Unattended
34.00
4.00
6
1
893
149-WILMINGTON
Distribution
Unattended
34.00
12.50
9
1
894
D17-WINSTON PARK
Distribution
Unattended
34.00
12.50
9
1
895
G121-WORTH
Distribution
Unattended
34.00
12.50
9
1
896
W354-YORK CENTER
Distribution
Unattended
34.00
12.50
7
1
897
H36-YORKTOWN
Distribution
Unattended
34.00
12.50
6
1
898
W12-YORKVILLE
Distribution
Unattended
34.00
4.00
9
1
899
J29-GORE ROAD
Distribution
Unattended
34.00
12.00
9
1
900
J45 - PINE BLUFF
Distribution
Unattended
34.00
12.50
9
1
901
A15-ZION
Distribution
Unattended
34.00
12.50
6
1
902
TOTAL OUTSIDE CHICAGO (UNDER 10MVA)
11,755.00
3,075.00
2203
372
903
SPARE TRANSFORMER-1
765.00
345.00
34.00
666
4
904
SPARE TRANSFORMER-2
345.00
138.00
34.00
2352
7
905
SPARE TRANSFORMER-3
138.00
69.00
180
3
906
SPARE TRANSFORMER-4
138.00
69.00
12.50
467
7
907
SPARE TRANSFORMER-5
138.00
34.50
137
2
908
SPARE TRANSFORMER-6
138.00
34.50
13.20
648
13
909
SPARE TRANSFORMER-7
138.00
13.20
1930
39
910
SPARE TRANSFORMER-8
69.00
12.50
266
7
911
SPARE TRANSFORMER-9
34.00
13.20
163
27
912
SPARE TRANSFORMER-10
34.00
4.16
179
30
913
SPARE TRANSFORMER-11
125.00
4.16
189
40
914
TOTAL Transmission Substations
14,715
6,003
1,326
30050
99
915
TOTAL Distribution Substations
54,685
10,302
718
39205
1670
916
TOTAL Generation Substations
917
TOTAL
69,400
16,305
2,044
69255
1769


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
  1. Report below the information called for concerning all non-power goods or services received from or provided to associated (affiliated) companies.
  2. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount billed to the respondent or billed to an associated/affiliated company for non-power goods and services. The good or service must be specific in nature. Respondents should not attempt to include or aggregate amounts in a nonspecific category such as "general".
  3. Where amounts billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote.
Line No.
Description of the Good or Service
(a)
Name of Associated/Affiliated Company
(b)
Account(s) Charged or Credited
(c)
Amount Charged or Credited
(d)
1
Non-power Goods or Services Provided by Affiliated
2
Information Technology
Baltimore Gas & Electric
1,111,279
3
Transmission Services
Baltimore Gas & Electric
4
Other
Baltimore Gas & Electric
13,401
5
Materials
Baltimore Gas & Electric
461
6
Mutual Assistance
Pepco Holdings LLC
7
Information Technology
Pepco Holdings LLC
203,673
8
Credit card I/C
Pepco Holdings LLC
9
Materials
Pepco Holdings LLC
1,414
10
Transmission Services
ComEd of Indiana
10,659,454
11
Materials
PECO Energy Company
12
Information Technology
PECO Energy Company
204,607
13
Mutual Assistance
PECO Energy Company
14
Transmission Services
PECO Energy Company
15
Financial Services - Direct
(a)
Exelon BSC
4,673,438
16
Communications Services - Direct
Exelon BSC
230,268
17
Human Resources - Direct
Exelon BSC
23,057,818
18
Legal Governance - Direct
Exelon BSC
3,330,477
19
Executive Services - Direct
Exelon BSC
42,056
20
Operation Services - Direct
Exelon BSC
10,153
21
Utility Services - Direct
Exelon BSC
214,928
22
Security Services - Direct
Exelon BSC
312
23
Regulatory Governmental Affairs - Direct
Exelon BSC
162
24
Real Estate Services - Direct
Exelon BSC
1,878,994
25
Transmission Services - Direct
Exelon BSC
250,441
26
Supply Services - Direct
Exelon BSC
181,227
27
Information Technology - Direct
Exelon BSC
139,825,244
28
Legal Services - Direct
Exelon BSC
5,090,050
29
BSC Other - Direct
Exelon BSC
6,222
30
Financial Services - Indirect
Exelon BSC
38,972,966
31
Communications Services - Indirect
Exelon BSC
5,556,907
32
Human Resources - Indirect
Exelon BSC
1,087,950
33
Legal Governance  - Indirect
Exelon BSC
22,090,020
34
Executive Services - Indirect
Exelon BSC
24,696,698
35
Operations Services - Indirect
Exelon BSC
426,306
36
Real Estate Services - Indirect
Exelon BSC
4,261,397
37
Security Services - Indirect
Exelon BSC
22,479,598
38
Utilities Services - Indirect
Exelon BSC
25,553,642
39
Supply Services - Indirect
Exelon BSC
9,807,180
40
Information Technology - Indirect
Exelon BSC
315,014,883
41
Regulatory Governmental Affairs - Indirect
Exelon BSC
3,479,762
42
BSC Other - Indirect
Exelon BSC
11,280,322
43
Other
Exelon InQB8R Consolidated
19
20
Non-power Goods or Services Provided for Affiliated
21
Real Estate & Facilities
Exelon BSC
7,083,238
22
Fleet Maintenance
Exelon BSC
1,165
23
Materials
Exelon BSC
30,747
24
Other
Exelon BSC
1,165,037
25
Construction, O&M & Admin Fees
ComEd of Indiana
701,710
26
Other
ComEd of Indiana
8,619
27
Information Technology
ComEd of Indiana
28
Merger/Acquisition
Exelon Corporation
29
Information Technology
Baltimore Gas & Electric
30,298
30
Legal Department Services
Baltimore Gas & Electric
44,378
31
Mutual Assistance
Baltimore Gas & Electric
114,248
32
Audit Services
Baltimore Gas & Electric
8,312
33
Materials
Baltimore Gas & Electric
107,888
34
Transmission Services
Baltimore Gas & Electric
71,140
35
Mutual Assistance
PECO Energy Company
6,560,895
36
Information Technology
PECO Energy Company
241,558
37
Legal Department Services
PECO Energy Company
45,042
38
Audit Services
PECO Energy Company
8,436
39
Materials
PECO Energy Company
24,556
40
Transmission Services
PECO Energy Company
109,570
41
Information Technology
Pepco Holdings LLC
42,416
42
Legal Department Services
Pepco Holdings LLC
65,353
43
Audit Services
Pepco Holdings LLC
12,240
44
Mutual Assistance
Pepco Holdings LLC
17,393
45
Materials
Pepco Holdings LLC
1,892
46
Transmission Services
Pepco Holdings LLC
143,856
42


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2023
Year/Period of Report

End of:
2023
/
Q4
FOOTNOTE DATA

(a) Concept: NameOfAssociatedAffiliatedCompany
2023 Exelon Business Services Company Service Areas & Cost Assignment Methods
Exelon Business Services Company, LLC (BSC) provides services to the Exelon system of companies. For discussion purposes, BSC is divided into three groups: 1) core shared services, 2) utility focused services, and 3) corporate governance. The following are descriptions of the service areas and the cost assignment methods applied when billing the services.
The discussion below summarizes the cost assignment methods which generally require direct billing of services to the extent possible, then allocation based on cost causative allocation methods of costs that cannot be directly assigned.
1) CORE SHARED SERVICES AREAS
The Core Shared Services Areas provide a variety of shared support and management services for the Exelon system of companies. These shared services include Information Technology, Security, Supply, Legal Services, Human Resources, Transportation and Real Estate.
Information Technology
Energy Delivery Solutions, Projects & Enterprise Solutions. Provides application support to the business units and centrally manages enterprise-wide applications and business unit specific projects.
Cost Assignment:
Costs for information technology applications which are specific to one Client Company are directly charged to the respective Client Company.
- Costs for information technology applications which benefit all or more than one Client Company are allocated to the respective Client Companies based on an appropriate cost causative allocation methodology, which varies from project to project.
Cloud and Infrastructure Engineering and Operations. Manages the enterprise IT infrastructure, provides infrastructure services, and ensures a safe and stable operating environment.
Cost Assignment:
Service costs are directly charged to IT Application Portfolios on a unit price basis for services such as mainframe, email, telephone, LAN, etc. IT Application Portfolio costs are directly charged to Client Companies when specific to one Client Company. IT Application Portfolio costs that benefit more than one Client Company are allocated based on an appropriate cost causative allocation methodology.
IT Governance. Comprises an IT Program Management Office and Business Office focused on establishing standard processes, procedures and methods and Enterprise Architecture and Planning responsible for comprehensive enterprise strategic planning and architecture standards and assurance.
Cost Assignment:
Service costs are allocated to Client Companies based on an IT Service Billings ratio of each Client Company or an appropriate cost causative allocation methodology.
Corporate & Information Security Services (CISS)
Includes the costs of providing Corporate and Information Security services for the Client Companies
Corporate Security and Analysis. Provides security policy development and alignment with policies and strategic initiatives; Intelligence gathering and analytical services across the corporation to include threat / risk assessments and recommendations.
Information Security. Develop, maintain and enforce a security strategy, policy and standards framework that aligns Exelon business need, legislative and regulatory requirements, and industry standard practices.
Physical Security. Includes corporate security functions such as security investigations and assessments, crisis management response and security related training.
Cost Assignment
Costs for Corporate and Information Security services which are specific to one Client Company are directly charged to the respective Client Company.
Service costs are allocated to Client Companies based on an IT Service Billings ratio of each Client Company or an appropriate cost causative allocation methodology which varies by service.
The physical security services are charged directly to Client Companies based on time and materials or allocated on the Modified Massachusetts Formula, an average of each Client Company's Gross Revenues, Total Assets and Direct Labor to the totals of all Client Companies.
Supply
Includes the costs of providing services related to the supply function for the Client Companies. Does not include costs of the materials/services purchased under the Purchase Orders/Contracts established by BSC Supply Services group or the purchase or sale of power.
Strategic Sourcing. Manages the sourcing of categories across Exelon, drives total cost of ownership, and manages supplier relationships.
Supply Operations. Provides tactical support to business unit operations. Embedded Supply employees perform these services for the Utilities.
Supply Support. Comprises e-business functions, supply projects, and diversity initiatives, as well as policies, programs, systems and decision support systems.
Cost Assignment:
Whenever possible, service costs are directly charged to Client Companies.
Remaining service costs are allocated to Client Companies based on various expenditure-spend methodologies (generally, the services and/or materials purchased by each Client Company).
Accounts Payable. Processes invoices and administers the P-Card (purchasing-card) program.
Cost Assignment:
Accounts payable service costs are directly charged to Client Companies on a unit price based on transactions processed for each Client Company.
Legal Services
Corporate & Commercial. Provides legal support for commercial contract negotiations, acquisitions, intellectual property, strategy, securities, financial reporting, real estate, nuclear related issues, bankruptcy, credit and collections, environmental, general corporate, and other transactional matters.
Environmental . Provides legal support for the defense of agency enforcement actions, compliance counseling, environmental matters relevant to permitting and re-licensing of generation facilities, support for safety and OSHA compliance, EHS compliance audits and NRC investigations.
Labor & Employment. Represents Exelon’s Client Companies in a wide range of employment related matters before agencies, arbitrators, and state and federal courts; provides advice and counsel on all labor and employment related matters.
Litigation. Provides legal support for all forms of disputes, including breach of contract, commercial disputes, personal injury, and property damage.
Regulatory. Represents Exelon’s Client Companies before various regulatory agencies, including the Illinois Commerce Commission, the Pennsylvania Public Utility Commission, Maryland Public Service Commission, New Jersey Board of Public Utilities, Delaware Public Service Commission, Public Service Commission of the District of Columbia and the Federal Energy Regulatory Commission.
Client Services. Comprised of the business functions of the Legal Department, including financial management, client billing, business planning and analysis, human resources, systems management, and general administration.
Cost Assignment:
Costs for lawyers and paralegals are directly charged to Client Companies when possible and the remaining services are allocated on the Modified Massachusetts Formula, an average of each Client Company’s Gross Revenues, Total Assets and Direct Labor to the totals of all Client Companies.
Human Resources
Human Resources is divided into two groups - (i) General HR activities, including support functions such as diversity, planning and development, employee health and benefits, compensation planning, management and employee development; HR planning, technology and metrics for HR field units; worker’s compensation administration; benefits administration services; payroll processing; HR Solutions Hub, HR/Payroll system maintenance and HR process improvement support and metric reporting; (ii) Labor Relations, including development and management of labor relations strategy in support of business units with represented employees.
Cost Assignment:
Whenever possible, service costs are directly charged to Client Companies.
Most general Human Resources Activities costs are directly charged to Client Companies on a unit price basis based on the total employee headcount of each Client Company. Payroll processing costs are directly charged to Client Companies on a unit price based on paycheck counts of each Client Company.
Labor Relations costs are directly charged to Client Companies on a unit price basis based on the headcount of represented employees of each Client Company or direct charged based on time and materials.
Transportation
Transportation. Coordinates corporate aircraft services.
Cost Assignment:
Service costs are directly charged to Client Companies on a unit price based on total occupied flight hours of each Client Company.
Real Estate
Includes real estate portfolio and asset management strategy, lease administration for facilities, land or infrastructure obligations, property management, mail services and other real estate consulting services, generally concentrating on non-utility and non-power plant operations.
Cost Assignment for the above mentioned area:
Service costs are allocated to Client Companies based on occupied square footage.
2) EXELON UTILITIES AREA
Exelon Utilities is comprised of a small utility-focused corporate governance and oversight function that will facilitate collaboration among the utilities to achieve the highest standards of organizational effectiveness, operational excellence, and customer and stakeholder satisfaction.
Utility Strategy & Policy includes utility-wide strategy formulation and implementation, regulatory policy/issue alignment and implementation, utility investment and business model strategy and scenario analysis and analytical support to the utilities.
Utility Oversight includes governance and oversight of a Peer Group structure that aligns across the client utilities to drive consistency, best practices and innovation in the core functions of the Management Model; tracks performance regarding key performance indicators, improvement initiatives and industry standards; analyzes opportunities and develops recommendations on issues pertinent to leadership; coordinate of the business planning process and provides oversight of Management Model documentation integration across the Utilities.
Cost Assignment for the above mentioned groups:
Whenever possible, service costs are directly charged to specific utility companies.
The remaining corporate governance costs that cannot be directly charged are allocated to the Utilities based on a utility variation of the Modified Massachusetts Formula, an average of each utility’s Gross Revenues, Total Assets and Direct Labor to the totals of all utility companies.
Transmission Strategy & Compliance manages the Exelon Utilities’ interface with the applicable regional transmission and reliability organizations, oversees the implementation of FERC Regulations, NERC Reliability Standards and EU Physical CISS Programs to ensure ongoing compliance, represents utilities’ interests and implements corporate strategy in both PJM Regional Transmission Organization and Regional Reliability Organization stakeholder proceedings, and also provides market intelligence and analytic support to strategic transmission studies and other initiatives as needed.
Cost Assignment:
Whenever possible, service costs are directly charged to specific utility companies.
Remaining service costs that benefit participating utilities are allocated for transmission related activities based on transmission peak load allocation.
Transmission System Operations Operate, control, and monitor Exelon transmission systems. Perform Transmission Owner Scheduling, System Control, and Dispatch Service functions per PJM Open Access Transmission Tariff Schedule 1A and fulfill all associated PJM Operating Agreement and PJM Manual obligations of local transmission control center for Exelon.
Cost Assignment:
Whenever possible, service costs are directly charged to specific utility companies.
Remaining service costs that benefit participating utilities are allocated for transmission related activities based on transmission peak load allocation.
3) CORPORATE GOVERNANCE AREAS
The Corporate Governance Areas house employees who provide corporate governance services for the Exelon system of companies. The Corporate Governance Areas in BSC include:
Finance. Includes Senior Executive Vice President and CFO Exelon, Finance, Treasury (cash management services), Controller, External Audit fees, Tax (consolidated Federal and state returns), Financial Planning and Analysis, Investor Relations, Capital Markets, Insurance Services, and External Reporting.
Compliance, Audit and Risk Services. Includes three separate but complementary teams: Compliance & Ethics, Enterprise Risk Management, Exelon Audit Services (Sarbanes Oxley compliance)
Executives and General Activities . Includes Exelon senior leadership positions including President and Chief Executive Officer and other Executive Committee members. Also includes general activities, such as income and other taxes, severance and interest, and Board of Directors costs and shareholder meetings.
Communications, Public Advocacy and Corporate Relations. Includes Exelon Corporation advertising/brand management, donations/contributions, sponsorships and annual report creation, shareholder/investor external communications, and other communication services; as well as Client Company public advocacy, advertising, coordination of donations/contribution approval, corporate/media relations, and corporate and external communications; public affairs activities; internal communications; and photography, videography and video production services. Embedded Communication employees also perform these services for the Utilities
Governmental and Regulatory Affairs and Public Policy . Includes executive oversight; management services for compliance with Federal laws, regulations and other policy requirements including relationship management with Congress, Administration and regulators; strategy development and lobbying and advocacy related to Federal legislative and regulatory initiatives; competition initiative activities; PAC administration and operation; grassroots activities; and Federal public affairs activities.
Legal Governance. Includes General Counsel and the Corporate Governance group (including the corporation’s compliance and ethics program and Corporate Secretary and shareholder services).
Corporate Development. Includes strategic expertise and governance in the evaluation and execution of merger and acquisition opportunities, evaluating company assets for divestiture opportunities, and providing financial and transactional support to restructuring projects.
Corporate Strategy, Innovation & Sustainability. Provides strategic support for senior leadership; program leadership for Exelon's sustainable growth strategy; and corporate-wide governance, oversight, and support for innovation, environment, and safety functions.
Investments. Includes determining the investment strategy and asset allocation of Exelon’s pension funds, VEBA post retirement funds, managing relationships with investment managers, overseeing daily investment activities and maintaining a well-diversified investment menu for the Employee Savings Plans. (Certain Investments Area costs are reimbursable by and therefore billed directly to the applicable funds and plans).
Cost Assignment for the Corporate Governance Areas:
Whenever possible, service costs are directly charged to Client Companies.
The remaining corporate governance costs that cannot be directly charged are allocated to Client Companies based on the Modified Massachusetts Formula, an average of each Client Company’s Gross Revenues, Total Assets and Direct Labor to the totals of all Client Companies.
(b) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
BSC - IT Direct Billing by FERC ACCT:
FERC
107000 $ 77,923,389 
107998 84,000 
108100 1,541,617 
182300 (89,452)
416000 1,245 
416004 1,820 
557000 989,653 
560000 (29,723)
561700 (293)
566000 731,381 
568000 (21,518)
569100 334,464 
569200 698,709 
569300 1,590,235 
570000 106 
571000 1,008 
580000 208,915 
586000 (530,783)
588000 24,231,212 
590000 (149,814)
592000 4,387 
593000 68,740 
598000 2,719,418 
903000 9,563,168 
908000 3,662,706 
923000 15,332,276 
930200 14,319 
935000 938,074 
184000 5,985 
Total $ 139,825,244 
(c) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
BSC - IT Indirect Billing by FERC ACCT:
FERC
107000 $ 192,307,368 
107998 373,000 
108100 2,071,596 
416004 2,429 
426100 2,593 
426500 1,895,319 
560000 (48,299)
561700 (440)
566000 8,228,035 
568000 (35,882)
569100 (33,701)
569200 174,153 
569300 (1,004,152)
570000 136 
571000 1,351 
580000 (120,073)
586000 427,954 
588000 18,829,921 
590000 (263,838)
592000 5,910 
598000 5,213,242 
903000 32,104,529 
908000 9,394,424 
923000 45,473,173 
925000 13,162 
930100 2,905 
935000 68 
Total $ 315,014,883 
XBRL Instance File
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